200401201st Response of ID Power to FEA Part III.pdf

IDAHO POWER COMPANY
CASE NO. IPC-O3-
FIRST PRODUCTION REQUEST
FEA
TT A CHMENT TO
RESPONSE TO
REQUEST NO. FEA-7(b)
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO INCREASE ITS RATES
AND CHARGES FOR ELECTRIC SERVICE
TO CUSTOMERS IN THE STATE OF IDAHO
IDAHO POWER COMPANY
DIRECT TESTIMONY
JOHN R. GALE
CASE NO. IPC-E-94-5
the policies of Idaho Power Company, analyzed customer
impact different rate designs prepared revenue
reports associated with chang ing rate structures
analyzed the rate structures other utilities,
coordinated the administration of the company s tariffs,
and prepared assorted cost studies.In March 1990, I was
assigned to the company s Meridian District Office for
one year where I held the position of Meridian Manager.
This position is part of a Company cross-training program
which provides office employees withcorporate
background field operations.March 1991,
returned to the Rate Department , and in July 1991, I was
promoted to Manager of Rates.As Manager of Rates, I am
responsible for the overall coordination and direction of
the Rate Department,including development
jurisdictional revenue requirements and class cost-of-
service studies , preparation of rate design analyses , and
administration of tariffs and customer contracts.
current duties also include the administration of the
Company's Power Cost Adjustment tariff.
Have you previously testified before the
Idaho Public utilities commission?
Yes.have previously testified
revenue requirement design CostandPowerrate
Adjustment ("PCA") issues.
GALE , Di
Idaho Power Company
What is the purpose of your testimony in
this proceeding?
I will testify as to the company's proposed
revenue allocation of the Idaho jurisdictional revenue
requirement to the Idaho customer classes and special
contract customers.am also sponsoring testimony
describing the relationship between the general rate
case and the Power Cost Adjustment.
What exhibits are you sponsoring?
I am sponsoring the following exhibits:
Exhibit Ti tIe Page
Revenue Allocation Summary
Power Cost Adjustment
Calculations
IPUC No. 26, Tariff No. 101 115
REVENUE ALLOCATION
How using revenuethetermareyou
allocation
I am referring to the process of spreading
the total Idaho jurisdictional revenue requirement to the
customer classes and special contract customers.
What is the Company I s primary objective for
revenue allocation in this proceeding?
The pr imary obj ecti ve move
continuously toward cost of service in order to price our
GALE, Di
Idaho Power Company
product consistently with the costs of providing it.
This objective applies both to revenue allocation and to
pricing.allocation tool addressRevenue
relationships between the customer classes and pricing is
a tool to address relationships within customer classes.
Ms. Brilz addresses pricing issues in her testimony.
Why is cost of service important in revenue
allocation?
allocating revenue according to cost
causation,subsidies can be limi ted between customer
groups.As the electric industry moves toward a new
competitive environment, the need to eliminate or reduce
subsidies and customer classesbetweenamong
underscored.It will become increasingly important to
cost and price correctly.Additionally, cost-of-service
based electric rates provide our customers with better
information upon which to make both energy consumption
and conservation decisions.
Are there other for revenuereasons
allocation to be guided by cost of service?
Yes.It provides a means for the Company
to objectively allocate revenue requirement among the
customer classes and special contracts.By following
costs,Idaho Power neither picks favorites nor selects
targets.The discussion centered cost causation
GALE,Idaho Power Company
and allocation rather than whether a certain customer
class warrants special rate consideration.
Finally, a movement toward cost of service
conforms to the past precedent of the Commission.
Case No. U-1006-265A ("Case 265A") the Commission used
the Company's Weighted 12 Coincident Peak ("W12CP") cost-
of-service the starting point revenueforstudy
allocation.These results were then moderated for rate
continui ty and recognition of an FMC interruptibili ty
credit , but the end result was a movement toward cost of
service for all customer classes.Case No. U-1006-185
("Case 185") also followed a moderated cost-of-service
approach to revenue allocation.
Are you advocating a total move to cost of
service at this time?
No.However , I am advocating significant
steps towards that goal.The opportuni ties to make
material changes to the overall cost structure have been
few with this proceeding being the secondonly
opportuni ty in ten years to make significant changes.
Should there be any 1 imi ting parameters in
moving toward cost of service?
Some limiting parameters on the amount of
increase are appropriate in order to mitigate the rate
impact to some customers.I concur with the Commission'
GALE , Di
Idaho Power Company
statement in Case 265A.Page 31 of Commission Order No.
21365 states:
There are important interests in rate
stability and continuity that preclude
extremely large shifts in revenues from
one large class another.
Furthermore the resul ts cost-of-
service studies are not so precise that
the magnitudes of "proper " shifts are
known with certa inty .
Accordingly complete move to cost of
service for all customer classes is not proposed.For
this proceeding, I am recommending that customer classes
not increased than twice overallthemore
jur isdictional increase.The upper parameter based upon
the Company s proposed overall 9 percent increase would
be 18 percent.
Please describe Exhibit No. 46.
Exhibit No.4 6 is titled Revenue Allocation
Summary and consists of four pages.Page 1 shows the
current allocation classes andrevenuecustomer
special contract customers under the normalized 1993 test
year at existing rate levels.Page 2 demonstrates the
revenue allocation based solely on the results of the
W 12 study perf ormed Brilz.revenueTheMs.
GALE, Di
Idaho Power Company
allocation incl udes overall percent increasethe
requested by the Company.Page 3 is a modified cost-of-
service approach to revenue allocation that includes an
percent increases to customer classes andcap on
special contract customers.Finally page 4 shows the
effect of eliminating Schedule 33 as a customer class and
consolidating these into Schedule Smallcustomers
General Service) and Schedule 9 (Large General Service).
What is the revenue allocation based purely
on cost-of -service results?
Col umn 5 on page 2 of Exhibit No.4 6 shows
the relative increases or decreases required to achieve
cost-of-service and column shows theresul t
corresponding average rates in mills per kilowatthour
( "kWh"
) '
. These numbers include the Company's requested
increase.When compared to the Company's request for an
overall percent Schedule (Residential Service) ,
Schedule 19 (Large Power Service), Schedule 33 (Public
Water Supply and Sewage system Power Service), Micron,
and Simplot are all reasonably close to cost of service.
Schedule 9 (Large General Service) and the unmetered rate
schedules are relatively overpriced while Schedule 7
Small General Service) ,Schedule (Irrigation
Service) ,and the Department Energy requireFMC
substantial increases to reach a cost-of-service result.
GALE, Di
Idaho Power Company
In my view , the substantial increases indicated by the
W12CP study need to be tempered in recognition of the
custo~ers' need for rate stability and rate continuity.
"..
The indicated also need tempereddecreases
primarily to offset the effect of capping the percentage
increase to the customer groups just mentioned.
I recommend moving all customer classes and
special contract customers toward cost-of-service with a
maximum revenue increase to an individual customer class
or special contract customer limited to 18 percent which
is twice the overall increase requested.This would
allow significant reductions to those classes that are
over-pay ing cost-of -service basis.Page
Exhibit No. 46 demonstrates a modified cost-of-service
approach to revenue allocation.
Please describe page 3 of Exhibit No.
more fully.
Column Exhibit No.page
indicates the percent increase to each customer class and
special contract customer with an upper parameter set of
18 percent.Schedules 7 and 24 , as well as FMC and the
DOE, are moved to the 18 percent limit.Schedules 1, 19,
and the Micron special contract and the Simplot
special contract are allocated revenue based upon the
cost-of-service results.Their increases are under the
GALE, Di
Idaho Power Company
18 percent cap.The unmetered schedules are reduced, but
not brought fully to cost of service.The total revenue
requirement then balanced with allocation tothe
Schedule 9.
How did the commission address the issue of
an additional credit for the ability to interrupt FMC in
Case 265A?
The Commission found that FMC' s cost
service the W 12 CP study should reducedunder
$1,732 497.The revenue requirement associated with this
reduction was spread to all customers including FMC.The
value of an interruptibili ty credit to FMC was also an
issue in Case 185.
Have included interruptibili tyyou
credi t to FMC in your proposal?
No.Under my proposal FMC is not fully
moved to cost of service because of the 18 percent upper
parameter.Line 13 on page 2 of Exhibit No.4 6 shows the
FMC revenue requirement of $40,192 358 based upon the
W12CP cost-of-service study.Line 13 on page 3 shows the
FMC revenue requirement after applying an 18 percent
increase.Since company proposed revenuethe
allocation to FMC is $1,778,918 less than the cost-of-
service result,it was not necessary to consider the
appropriateness of an additional credit to FMC.
GALE, Di
Idaho Power Company
Why have you consolidated Schedule 33 into
the general service schedules (Schedules 7 and 9)?
Most the Company'" end use rate
schedules consolidated into servicegeneralwere
schedules at the conclusion of Case 185 by Order No.
17856 issued in February of The consolidation1983.
included schedules for service to schools and churches.
Schedule remaining with thetheholdover.
realignment of Schedule 9 revenues , this is an opportune
time to blend Schedule 33 customers into the existing
general service schedules.
What final recommendation foryour
revenue allocation?
The final recommendation appears on page
of Exhibit No. 46.This revenue allocation collects the
requisite revenue requirement, conforms to the parameters
previously described , moves significantly toward cost of
service mi tigates shock,limits subsidies andrate
facili tates pr icing scheduleandratecomponent
determination.
POWER COST ADJUSTMENT
Were you involved in the development and
implementation Company CostIdahoPowerPower
Adjustment?
I was a member of the Company teamYes.
GALE, Di
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
J. GALE
Revenue Allocation Summary
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4
IDAHO POWER COMPANY
CASE NO. IPC-O3-
FIRST PRODUCTION REQUEST
FEA
TT A CHMENT TO
RESPONSE TO
REQUEST NO.FEA-7(c)
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO INCREASE ITS RATES
AND CHARGES FOR ELECTRIC SERVICE
TO CUSTOMERS IN THE STATE OF IDAHO
CASE NO. IPC-E-94-S
IDAHO POWER COMPANY
DIREC~ TESTIMONY
MAGGIE BRILZ
Please state you name and business address.
My name is Maggie Brilz.My business
address is 1221 West Idaho street, Boise, Idaho.
By whom employed and in whatareyou
capaci ty?
I am employed by Idaho Power Company as
Rate Design supervisor.
Please describe your educational background
and work experience.
In May of 1980 I received Bachelor of Arts
Degrees in Economics and Psychology from smith College in
Northampton,Massachusetts.June 1980From
November of 1984 I was employed by Learned-Mahn, Inc. in
Boise, Idaho as a systems Analyst.I started employment
wi th Idaho Power Company in November of as a1984
Financial Analyst in the Planning Department.In 1986 I
was promoted to the position of Rate Analyst in the Rate
Department.My duties as a Rate Analyst included the
development alternative pricing thestructures,
analysis of the impact on customers of rate design
changes, the preparation of cost-of-service studies, and
the administration of the Company's tariffs.In July of
1993 I was promoted to my current position of Rate Design
Supervisor.result,addi tionallynow
responsible for the overall rate design activities of the
BRILZ, Di
Idaho Power Company
Rate Department.
What is the scope of your testimony in this
proceeding?
My testimony will address the company' s
class cost-of-service study and the Company's rate design
proposals for the tariff and special contract customers.
Class Cost-of-Service studY
Please describe the methodology used to
prepare the class cost-of -service study submitted in this
proceeding.
The class cost-of-service study submi tted
in this proceeding uses the Weighted 12 Coincident Peaks
allocation method.This study uses the same methodology
as previously filed by the Company in Case No. U-1006-185
and Case No. U-1006-265A and used by the Commission in
the allocation of the revenue requirement among customer
classes in those cases.
What procedures used thewere
preparation of the fully distributed or embedded class
cost-of-service study?
There two general usedstepsare
preparing a fully distributed or embedded class cost-of-
service study.The first step is to determine the total
costs of providing electric service as measured through
the use of the company's accounting data for a specified
BRILZ, Di
Idaho Power Company
period, adjusted for normal weather and water conditions.
The next step is to establish a methodology for the
separation of costs among classes of service.
What total costs providing electric
service have been allocated to the various classes of
service in the class cost-of-service study?
The total system costs providing
electric service to the Idaho jurisdiction included on
Mr. Obenchain s Exhibit No. 20 have been allocated to the
various classes.
What methodology used for thewas
separation of costs among classes of service?
The methodology for separating costs among
classes consists three-step generallyprocess
referred to as classification, functionalization, and
allocation.In all three steps, recognition is given to
the way in which the costs are incurred by relating these
costs to the way in which the utility is operated to
provide electrical service.
Please explain meaningthe
classif ication.
Classification refers to the identification
of cost as being either customer-related, demand-related,
or energy-related.These three cost components are used
to reflect the fact that an electric utility is not
BRILZ, Di
Idaho Power Company
simply in the business of selling electric energy, even
though it may sometimes appear to the customer that only
energy, as measured in kilowatt-hours, is purchased.
fact, the customer is also buying the ability to have
service available at a point in time. That the customer
may request and at any time receive service refers to
this item of availability.Secondly,the customer is
buying capacity or the ability to receive as much power
as is required at a point in time. Most power supply
facilities (generation and transmission) generally are
considered to fall into this category. And finally, the
customer is buying energy or the ability to do useful
work extended period time.threeTheseover
concepts of availability, capacity and energy are related
to the three components of cost designated as customer,
demand and energy components , respectively. In order to
classify particular component,pr imarycost
attention is given to whether the cost varies as a result
of changes in the number of customers changes in demands
imposed by the customers, or changes in energy use.
What examples customer- ,are some
demand-, and energy-related costs?
Examples of customer-related costs are the
investment portion investmentmeters,the
associated with distribution facilities, meter reading,
BRILZ, Di
Idaho Power Company
billing, and the costs associated with maintaining the
availabili ty of service regardless of whether service is
actually taken.Demand-related costs are investments in
generation, transmission, and distribution plant and the
associated operation and maintenance expenses necessary
to accommodate the maximum rate of use (demand) imposed
on the company'Energy-related costs aresystem.
generally the variable associated thewithcosts
operation the generating fuel,suchplants,
although with hydro production a portion of the plant
investment is usually classified as energy-related.
Please discuss usedtheapproach
classify customer-, demand- and energy-related costs.
The Company has used the Electric utility
Cost Allocation published NationalManualthe
Association of Regulatory utility Commissioners as its
primary guide to the classification of customer-demand-
and energy-related costs.
Please explain meaningthe
functionalization.
In addition to classification, costs must
functionalized;is,identified with utilitythat
operating functions. Operating functions recognize the
different roles played by the various facilities in the
electric utility system. In the company's accounts these
BRILZ, Di
Idaho Power Company
various roles are already recognized to some degree
particularly recording plant coststhe
production,tr ansmi s s i on distribution related.
However, this functional breakdown is not in sufficient
detail for cost-of-service purposes.Individual plant
items are examined and , where possible , the associated
investment costs are assigned to one or more operating
functions so that the costs may be allocated among
classes of customers.
Please explain the process of allocation.
The process of allocation is merely one of
apportioning the total jurisdictional cost among classes
by introducing allocation factors into the process. An
allocation factor is nothing more than an array of
numbers which specifies the class value or share of a sum
total jurisdictional quantity.
Once individual costs have been allocated
to the various classes of service,it is possible to
total these costs as allocated and thus arrive at a
breakdown of utility rate base and income by class, much
set financial deri ved forstatements
subsidiaries of a single company.
The results are stated in a summary form to
measure adequacy of revenues for each class. The measure
of adequacy is typically the rate of return earned on
BRILZ, Di
Idaho Power Company
rate base which is compared to the requested rate of
return.
Have prepared supervised theyou
preparation of the fully distributed or embedded class
cost-of-service study submitted in this proceeding?
Yes. Using the cost information provided to
me by Mr. Obenchain and the Company I s own load research
data, I prepared the fully distributed or embedded class
cost-of-service study.This study was prepared using the
Weighted 12 Coincident Peaks allocation method.
identified as follows:
It is
Exhibit Description
Exhibit No. 30 Functionalization and
Classification of Costs
Exhibit No. 31 Summary of Functionalized Costs
Exhibit No. 32 Allocation to Classes
Exhibit No. 33 Development of Weighted Demand
and Energy Allocators
Exhibit No. 34 Revenue Requirement Summary
Please describe Exhibit No. 30.
Exhibi t No.conta ins and130pages
consists of 10 Cost Functionalization and Classification
Tables. The functionalization and classification of each
component of rate base, operating revenue and expense is
treated in detail in these tables.The tables are shown
BRILZ, Di
Idaho Power Company
in the following sequence:
Table No.Description
Electric Plant in service
Accumulated provision for Depreciation
Addi tions and Deletions to Rate Base
Operating Revenues
Operation and Maintenance Expenses
Depreciation and Amortization Expense
Taxes Other Than Income Taxes
Income Taxes
Development of Labor Related Allocator
Functionalization Allocators
What is the signif icance of the column
headed "Allocator
This column identifies,symbol,the
basis for each allocation. For example, for Accounts 310
through 316, steam Production, shown at line 20 on page
1, the constant "PI-S" is used to allocate the total
investment in steam production plant to the appropriate
functions.The resultant functionalization of costs may
itself serve as a basis for subsequent allocations.This
use is illustrated at line 138 on page 21 where the
accumulated depreciation for steam production plant is
allocated by the functionalization of costs at line 20.
Please describe the classification of plant
BRILZ, Di
Idaho Power Company
utilized in the class cost-of-service study.
In the class cost-of-service study all
steam and hydro production plant has been classified on
a demand and energy basis using the methodology found
preferable by this Commission in prior general rate
proceedings. The energy portion of the steam and hydro
production investment has been determined by use of the
Idaho jurisdictional load factor of 67.57 percent. By
application of the load factor ratio to the steam and
hydro production investment,the fixedplant
energy-related portion is easily determined. The balance
of the steam and hydro production plant investment is
then classif ied as demand-related.All other production
plant and transmission plant has been classified as
demand-related.
Would descr ibe functionalyouthe
categories used for assignment of transmission plant and
distribution substations?
A description of the functional categories
used for assignment transmission plant and
distribution substations is as follows:
Power Supply System facili ties are the
facilities that form the bulk power transmission system
together with transmission and substationstep-up
facilities required to introduce the company's generation
BRILZ, Di
Idaho Power Company
into the power supply system.
Transmission service refers to facilities
rated at 161 kV through 46 kV that are not identified as
part of the power supply system. Facilities rated at 69
kV and 46 kV are generally localized in the service they
provide, particularly to distribution substations.
Distribution Function refers to substation
facilities that are not considered part of transmission
service.
Direct Assignment refers to facilities that
can be identified as serving specific customers.
Distribution plant Accounts 364, 365, 366,
367 and 368 were functionalized in accordance with the
NARUC methodology referred to earlier in my testimony.
Specifically, the primary and secondary investments of
each plant account were obtained from the books and
records the Company and then classified between
capacity and customer components using the normalized
minimum use for the average customer under actual usage
conditions on Idaho Power s system.
Would please descr ibe theyou
functionalization of general plant?
General plant was functionalized based on
total production, transmission, and distribution plant.
As a result, a portion of general plant was assigned to
BRILZ, Di
Idaho Power Company
each production, transmission, and distribution function
based on each function's proportion to the total.
How the accumulated provision forwas
depreciation functionalized?
The accumulated provision for depreciation
was functionalized using the resulting functionalization
of costs for the appropriate plant item.For example,
the accumulated depreciation for steam production plant
shown at line 138 on page 21 is functionalized based on
the functionalization steam production plant
service at line 20.
Please describe Table 3 of Exhibit No. 30.
Table 3 indicates the functionalization of
all other additions to and deductions from rate base.
Deductions from rate base include customer advances for
construction accumulated deferred income taxes.and
Customer advances have been functionalized based on the
distribution plant investment against which the advances
apply.Accumulated deferred have beentaxes
functionalized based total plant investment.
Additions to rate base consist of materials and supplies,
which have been functionalized based on the appropriate
plant function,fuel inventory,which beenhas
functionalized based on energy production, and prepaid
items, which have been functionalized based on labor
BRILZ, Di
Idaho Power Company
expenses.Deferred conservation expenses have been
functionalized based production theenergyand
electric acquisi tion adjustment has beenplant
functionalized based on the type of plant acquired from
prairie Power.
Please describe the functionalization of
other revenue shown on Table 4 of Exhibit No. 30.
other revenue is functionalized based on
either the functionalization of the related rate base
item or, in the situation where a particular revenue item
may identified with specific service,the
functionalization of the specific service item.
Briefly descr ibe method whichthe
operation and maintenance expenses were functionalized.
The functionalization operation and
maintenance expenses is detailed on Table 5 of Exhibit
No. 30.In general, the basis for the functionalization
may be readily interpreted from the Exhibit, particularly
since in most cases the functionalization is the same as
that for the associated plant.
How is supervision and engineering expense
treated throughout the allocation operation and
maintenance expenses?
For each applicable expense account in each
functional the labor component is separatelygroup,
BRILZ, Di
Idaho Power Company
functionalized in accordance with the detail provided on
Table 9 of Exhibit No. 30. Referring to pages 106 through
116 of Table 9,it can be seen that the total of
allocated labor in each functional group becomes the
basis the functionalization supervision andfor
engineering expense. For example, for Account 535, the
labor related supervision and engineering expense is
functionalized based on lines 689-693 which represent the
cumulative labor as functionalized f or Accounts 536
through 540 shown on page 106 of Exhibit No. 30. In a
similar fashion,allocation supervision andthe
engineering associated with hydraulic maintenance expense
is based on the composite labor expense for Accounts 542
through 545,as expressed by lines 696-699.Total
functionalized labor serves the addi tionalexpense
purpose of functionalizing employee pensions and other
labor-related taxes and expenses. Table 9 details the
development all labor-related functionalization
factors used in this study.
Please describe the functionalization of
depreciation expense, taxes other than income, and income
taxes shown on Tables 6, 7, and 8, respectively.
Depreciation functionalizedexpense
based on the function of the associated plant.Taxes
other than income are also functionalized based on the
BRILZ, Di
Idaho Power Company
function of the source of the tax.Def erred income taxes
are functionalized based on total plant investment.The
functionalization of federal and state income taxes is
based on the functionalization of total rate base and is
discussed in more detail in my testimony regarding the
allocation of costs to classes of customers.
Please describe Exhibit No. 31.
Exhibit No. 31 summarizes in row format the
functionalized costs for each component of rate base and
expenses shown across the columns on Exhibit No. 30.
Please describe Exhibit No. 32.
Exhibit No. 32 details the "allocation of
the summarized costs shown on Exhibit No. 31 to each
class service including special contractthe
customers.The Exhibit also includes a summary of
resul ts showing the actual rate of return earned for each
customer class and special contract customer.The
Exhibit includes the following tables:
Table No.Description
Plant in Service.
Accumulated Reserve for Depreciation
Amortization Reserve
customer Advances for Construction
Accumulated Deferred Income Taxes
Acquisition Adjustment
BRILZ, Di
Idaho Power Company
working Capital
Deferred Programs
Subsidiary Rate Base
other Revenue
operation & Maintenance Expenses
Depreciation Expense
Amortization of Limited Term Plant
Taxes other Than Income
provision for Deferred Income Taxes
Investment Tax Credit Adjustment
state Income Tax
Federal Income Tax
Allocation Factor Summary
Briefly describe the manner in which you
allocated the summarized costs shown on Exhibit No. 31 to
each class of service as shown on Tables 1 through 16 of
Exhibit No. 32.
effort weight the monthly
contributions to the total system peak in a fashion which
reflects the marginal costs of the company's seasonal
load requirements, I have allocated demand- and energy-
related costs according to the weighted 12 coincident
Peaks allocation method.To develop the desired weighted
demand- and energy-related allocation factors, I used the
monthly generation level coincident demands and
BRILZ, Di
I daho Power Company
normalized energy usage of each of the Company s special
contract customers and each class of tariff customers
multiplied by the corresponding monthly marginal costs.
I then totaled the results for each customer class and
divided the customer totals by the jurisdictional total
weighted value to establish the ratio of the weighted
factor for each class.The details of the development of
the weighted demand allocation factors used for the
allocation of the demand-related portion of production
plant and for the allocation of both power supply and
transmission service transmission facilities are shown on
Exhibit No. 33.These allocation factors are designated
as D10, D11, and D13 respectively. The detail for the
development of the weighted energy allocation factor used
for the allocation of the energy-related portion of
production plant can also be found on Exhibit No. 33.
The energy allocation factor is designated as E10.
Have the marginal been usedcosts
develop the company's revenue requirement?
No.The marginal have been usedcosts
solely for purposes of developing allocation factors and
not for purposes of developing the company's revenue
requirements.
What was the method by which you allocated
costs associated with distribution plant?
BRILZ, Di
Idaho Power Company
The allocation of the capacity components
of distribution plant, both primary and secondary, was by
use the coincident peak demands eachgroupfor
customer class identif ied as demand allocation factors
D20, D30, D50, and D60. The allocation of the customer
components distribution both pr imary andplant,
secondary, was by use of the average number of customers
identified as customer allocation factors C20, C30, C50
and C60.
What was the method by which you allocated
costs associated with customer accounting and customer
information?
The pr incipal customer-related expenses
which require allocation are meter reading expenses,
customer records and collections, uncollectible accounts,
and customer assistance expense. The meter reading and
customer account expenses were allocated based upon a
review of actual practices of Idaho Power Company in
reading and preparing monthly bills.Themeters
allocation of uncollectible amounts again was based upon
a review of actual Idaho Power Company data.Customer
assistance expenses were allocated based on the average
number of customers in each class.
Does Exhibit No. 32 include a listing of
the allocation factors used to allocate to classes the
BRILZ, Di
Idaho Power Company
various costs shown on Tables 1 through 16?
Yes.Table 19 includes a listing of each
allocation factor.
How did you allocate state and federal
income tax to each customer class and special contract
customer as shown on Tables 17 and 18?
The state and federal income taxes for the
Idaho jurisdiction provided to me by Mr. Obenchain were
allocated to each customer class and special contract
customer on the basis of income before income taxes.The
worksheet showing this allocation is included in my
workpapers.Tables 17 and 18 show the functionalization
of these allocated taxes to each customer class.
What method was used to functionalize the
state and federal income taxes as shown on Table 17 and
Table 18 of Exhibit No. 32?
state and federal income weretaxes
functionalized based on the functionalization of total
rate base for each class.For example , the total power
supply production amount of $88,220,224 allocated to the
residential class on Tables 1 through 9 of Exhibit No. 32
represents 18.54 percent of the total rate base amount of
$475,952,822 allocated to the residential class.The
state and federal income allocated thetaxes
residential ($1,087,682 and $9,251,772,class
BRILZ, Di
Idaho Power Company
respecti vely)are multiplied by this same percent to
establish the power supply production components
$201,607 and $1,714,862 shown on Table 17 and Table 18.
This methodology used all funct i ona forsame
components and customer classes shown on Tables 17 and
18.
Please describe Exhibit No. 34.
Exhibit No. 34 is the revenue requirement
summary based on the results of the class cost-of-service
study.The section headed "Revenue Requirement for Rate
Design" details the sales revenue required from each
customer class and special contract customer. The sales
revenue required includes return on rate base,total
operating expenses, and incremental taxes computed using
the net-to-gross multiplier of 1.642 provided to me by
Mr. Obenchain.I have provided the results from this
section to Mr. Gale.Mr. Gale's testimony addresses the
issue of the allocation of revenue requirement among the
customer classes.
Were any adjustments made to the Company I
data for any of the customer classes for purposes of the
class cost-of-service study?
Yes.As mentioned briefly by Mr. Obenchain
in his testimony, an adjustment was made to the actual
data for Micron to reflect the expected usage at that
BRILZ, Di
Idaho Power Company
customer's contract level of 37,000 kW.Additionally,
adjustments were made to the actual data for the Large
General service Power service customersandLarge
Schedules 9 and 19 respectively.
Please describe the adjustments made for
Micron.
The monthly billing demand for Micron was
determined by first calculating the ratio of billed
demand to contract demand for Micron' s actual 1993 test
year data, and second, by applying this ratio to Micron ' s
current contract level of 37,000 kW.Micron's monthly
billing calculated mul tiplying theenergywas
resultant billing demands by Micron' s actual monthly load
factors.The calculated monthly billing energy amounts
were then adjusted for losses to represent energy at the
generation level.These adjusted energy amounts were
used determina t i on the weighted energythe
allocator E10.The coincident peaks used the
determination of the weighted demand allocators D10, D11,
and D13 for Micron were calculated by multiplying 37,000
kW by Micron s actual monthly coincidence factors and
adjusting the resultant values for losses to represent
generation level coincident peaks. The details for these
calculations are included in my workpapers.
What adjustments were made to the Large
BRILZ, Di
Idaho Power Company
Power Service customer class?
The current rate structure for Large Power
service (Schedule 19), which includes a Basic Charge for
Basic Load Capacity, became effective on January 1, 1993.
However,the first billing f or the Company'cycle
January, 1993 billing period began on December 23, 1992.
As a result, customers whose meters were read between
December and 31 were not billed for Basic Load
Capacity.The actual data for the Large Power Service
customers for the January billing period was adjusted to
reflect Basic Load Capacity for the first six cycles of
the January, 1993 billing period.
What adjustments were made to the Large
General Service (Schedule 9) customer class?
As I will discuss in more detail in my
testimony pertaining to rate design,the Company is
proposing to raise the threshold for service eligibility
under Schedule 19 from 750 kW to 1,000 kW.As a result,
41 customer currently taking service under Schedule 19
will no longer qualify for that schedule.The demand and
energy allocators as well as any direct assignments of
plant investment and revenue for both the Large Power
Service and Large General Service customer classes were
adjusted to reflect the movement of these 41 customers
from Schedule 19 to Schedule 9. These adjustments are
BRILZ, Di
Idaho Power Company
reflected in my workpapers.
Rate Desiqn
What are the objectives the Company
striving to achieve through its rate design proposals?
The Company is striving to achieve two main
obj ecti ves.First,the Company is striving to give
customers price signals to encourage a more efficient use
of energy and a more optimal utilization of the Company'
system.Second, the Company is striving to establish
prices which reflect the costs of the services provided.
Cost based prices give customers clear signals about the
costs of recei ving service,reduce subsidies within
customer classes, and result in a more equitable recovery
of the costs of providing service.
How does the Company propose to implement
these objectives?
The Company proposes to implement these
objectives by aligning revenue allocation among the
classes with service,implementingcost
distribution capacity pricing in the form of a Basic
Charge on all demand metered schedules , and by adopting
Customer Charges on all metered schedules.Mr. Gale has
provided testimony on the revenue allocation among the
classes.My testimony addresses the Company'rate
design proposals which include the implementation of a
BRILZ, Di
Idaho Power Company
Basic Charge and the adoption of a Customer Charge.
What is the purpose of the Basic Charge?
The purpose of the Basic Charge
recover the capacity-related costs of the distribution
facilities in place to serve customers by charging for
the peak demands placed on the Company I s system.
How does recovering the capacity-related
costs of the distribution facilities in place to serve
customers meet the objectives you outlined earlier for
the Company I s rate design proposals?
By recovering the capacity-related costs of
the distribution facilities through a Basic Charge the
Company is giving customers a clearer signal about the
relationship between the demands the customers place on
the Company I s system and the costs of providing the
facilities to serve those demands.The Basic Charge also
gives customers the price signal to minimize peak demand
and encourages a more balanced use of system facilities.
Because the Basic Charge recovers the capacity-related
costs of the distribution facilities, it also reduces
subsidies within classes.
How does the Basic Charge reduce subsidies
within classes?
The Basic Charge recovers capacity costs
relating to the Company I s investment in distribution
BRILZ, Di
Idaho Power Company
facili ties constructed provide customers'peak
demands. A Demand Charge recovers revenue only for the
amount of capacity metered in any month. Thus, customers
whose monthly demand throughout the variesyear
relatively widely from the annual peak make a smaller
contribution the the company'towards recovery
investment in the distribution facilities installed to
serve that peak than do customers whose peak usage is
steady throughout the year.The result is a cross-
subsidy customers wi steady use to thefrom the
customers with widely variable use.A Basic Charge,
because it recovers revenue based on a customer s annual
peak,resul ts contribution towards thelarger
recovery of the company'investment in distribution
facilities from customers with variable demands.
What is the purpose of a customer Charge?
A Customer Charge is intended to recover
costs that do not vary with the amount of energy or
capacity used.As mentioned earlier in my testimony,
customer-related costs include such items the
investment portion investmentmeters,the
associated with distribution facilities , meter reading,
billing, and the costs associated with maintaining the
availabili ty of service regardless of whether service is
actually taken.
BRILZ, Di
Idaho Power Company
How does the implementation of a Customer
Charge meet the Company's rate design objectives?
customer Charge,because more
accurately reflects the cost of providing service than
does the melding of the customer costs into the energy
rate, gives customers a clearer signal as to the costs of
being connected to the company's system.As with the
Basic Charge, a Customer Charge also reduces subsidies
within classes.
What are the pricing objectives for the
company's various service schedules?
First,the Company plans initiate a
customer Charge all metered service schedules.
Second, the Company plans to add capacity pricing in the
form of a Basic Charge to demand-metered schedules which
do not currently include a Basic Charge.Third, the
Company plans to place more emphasis on the demand
component in its overall rate structure.And finally,
the Company plans to place less emphasis on the energy
component by minimizing increases to , or decreasing, the
energy charges on demand-metered schedules.The Company
does not plan to change the rate structure for unmetered
schedules or for the special contract customers.
How were the pricing objectives for the
design rates for each metered customer class
BRILZ, ci
Idaho Power Company
priori tized?
Al though an occasional exception to the
prioritization of the Company's objectives has been made
in order to meet other rate making objectives the
general priority of the Company's pricing objectives is
as follows:
Establish the Customer Charge at 15 percent
of the cost-of-service level.
Establish the Basic Charge at the cost-of-
service level.
Establish consistent Demand Charges among
the demand-metered schedules.
Establish the Energy Charge at the level
needed to collect the revenue requirement once the Basic,
Customer , and Demand Charges have been established.
Mr. Gale makes reference in his testimony
to the Company'proposal to eliminate Schedule 33
Public Water Supply and Sewage Treatment,and move
customers currently taking service under Schedule 33 to
either Schedule 7 Schedule depending on each
customer's usage. Would you please explain the Company'
proposal?
Yes.It is the Company's position that
customers should be placed on service schedules based on
their usage characteristics and not on their end-uses.
BRILZ, Di
Idaho Power Company
In Order No. 17856 issued in Case No. U-1006-185, the
commission approved the Company I s proposal to eliminate
Schedule 25, School All-Electric, and Schedule 34, Church
All-Electric, and to consolidate the customers taking
service under these two schedules onto the newly created
Schedules 7 and 9.Again in Order No. 24406 in Case No.
IPC-E-92-7,the commission approved the Company I S
proposal to eliminate Schedule 18, Uniform Rate Agreement
- Nonindustrial Service, and to consolidate the customers
taking service under that schedule onto Schedule 19.
order continue movement from end -usetheaway
schedules, the Company is proposing that Schedule 33 be
eliminated with the customers currently being served
under that schedule moved to ei ther Schedule
Schedule 9.
Should the commission determine that
Schedule 33 should not be eliminated, what would you
propose as the rate structure for that schedule?
Should the commission determine that
Schedule 33 not be eliminated, I propose that the same
rate structure proposed for the Company I s other demand-
metered schedules, which includes both a Customer Charge
and a Basic Charge, be adopted.
Are you proposing any other changes that
will require customers to be moved from the schedule
BRILZ, Di
Idaho Power Company
under which arethey
different schedule?
currently being served
Yes.As I will discuss in more detail
later, the Company is proposing to raise the ceiling for
service eligibility on Schedule 9, Large General Service,
from 750 kW to 1,000 kW.Correspondingly, the Company is
proposing to raise the threshold for eligibility on
Schedule 19, Large Power Service, from 750 kW to 1,000
kW.As a result of this change, 41 customers taking
service under Schedule 19 during the 1993 test year will
be moved to Schedule
Have you prepared supervised the
preparation of certain exhibits relating to your rate
design testimony?
Yes.sponsor ing followingthe
exhibi ts relating to rate design:
Exhibit
Exhibit No. 35
Exhibit No. 36
Exhibit No.3 7
Exhibit No. 38
Description
Class Cost-of-Service unit Costs
Summary of Revenue Impact and
Calculation of Proposed Rates
Billing Comparisons and Rate
Design ProposedImpacts
Rates
Service Schedules for Proposed
Rates
BRILZ, Di
Idaho Power Company
Exhibit No. 39 Summary of Charges and Basis
for Rates
Exhibit No.4 0 Derivation of Standby Charges
Exhibit No. 41 Summary of Revenue Impact and
Calculation of Interim Rates
Exhibit No.4 2 Billing Comparisons and Rate
Design Impacts of Interim Rates
Exhibit No. 43 Service Schedules for Interim
Rates
Please describe Exhibit No. 35.
Exhibit No. 35 shows the unit cost for each
function for metered service schedules as determined
through the fully distributed or embedded class cost-of-
service study.The billing units shown in the column
labeled either (G)or (X) reflect the actual billing
demands,normalized billing and numberenergy,
billings.The unit costs shown on Exhibit No. 35 form
the basis of the component charges for each service
schedule.
Please describe Exhibit No. 36.
Page 1 of Exhibit No. 36 is titled Summary
of Revenue Impact Each service schedule and special
contract customer is listed with its number of customers,
energy sales, and current revenue level.Column 5 shows
the revenue adjustment to each customer class.Column 6
BRILZ, Di
Idaho Power Company
shows the revenue to be recovered by the rate design
proposals based on the 1993 test year.Page 1 also lists
the mills per kWh and percentage change in revenue for
each customer class and special contract customer.
Pages through Exhibi t No.
indicate rate calculations made,billingthe
component, for each service schedule and special contract
customer.
Please describe Exhibit No. 37.
Exhibi t shows the impactNo.
customers I bills the proposed designs forrate
Schedules 1, 7, 9, 19, and 24.
Please describe Exhibit No. 38.
Exhibi t includes Company'No.the
service schedules indicating in legislative format the
changes associated with the proposed rate design made to
those schedules.
Please describe Exhibit No. 39.
Exhibit No. 39 shows in summary format the
proposed rates and the basis for the proposed rates for
each of the Company I s metered service schedules.
Please describe Exhibit No. 40.
Exhibit No. 40 details the derivation of
the charges proposed for Standby Service under Schedule
45.
BRILZ, Di
Idaho Power Company
Please describe Exhibit Nos. 41, 42,and
43.
Exhibit Nos. 41, 42, and 43 show the rate
calculations, the impact on customers I bills, and the
revised service schedules proposed for the interim period
between the issuance of the Commission's Order in this
proceeding and the implementation of the proposed rate
designs.
How have you organized your discussion of
the Company I s rate design proposals?
have di vided discussion the
Company's proposed rate designs into six sections.The
first section includes the discussion for the proposed
rate structures for the Company I s non-demand metered
schedules.The second section includes the discussion
for the proposed rate structures for the Company I S non-
metered schedules.The third section addresses the
company's proposals for demand-metered schedules.The
fourth section addresses the Company's proposals for the
special contract customers.The fifth section includes
the rate design proposals for the Company I rider"
schedules for standby and alternate distribution service.
The final section discusses the Company I S plan for
implementation of the new rate structures and the rates
to be charged during the interim period.
BRILZ, Di
Idaho Power Company
NON-DEMAND METERED SCHEDULES
What are the company' s non-demand metered
service schedules?
Residential Service Small Generaland
Service, Schedules 1 and 7 respectively, are metered for
kilowatthour (kWh) use only.
What is the present rate structure for
Residential Service under Schedule 1?
Presently, residential customers pay only
an Energy Charge which also recovers the demand- and
customer-related costs. Residential customers are subject
to a $7.50 monthly minimum charge which includes up to
159 kWh of energy use.Approximately four percent of the
total billings in the test year were minimum bills
representing approximately six-tenths of one percent of
the residential revenue.
What requirement to betherevenue
recovered from Residential Service takingcustomers
service under Schedule 1?
Based on Mr. Gales ' Exhibit No. 46, the
annual revenue to be recovered from Schedule 1 customers
is $184,316,743.
Please describe the rate design proposal
for Schedule
The rate design proposal for Schedule 1 is
BRILZ, Di
Idaho Power Company
included on page 2 of Exhibit No. 36.The $7.50 minimum
charge has been replaced by a $2.50 customer Charge.The
$2.50 Customer Charge represents approximately 15 percent
of the cost-of-service result of $16.99 shown at line 300
on page 1 of Exhibit No. 35.The Energy Change remains
flat and increases from 4.70169 per kWh to 5.0211C per
kWh.
What impact does this rate design have on
Residential Service customers?
The typical monthly billing comparison for
Residential service on pagecustomersappears
Exhibit No. 37.
What is the present rate structure for
Small General Service under Schedule 71
Customers taking service under Schedule 7
presently pay only an Energy Charge , similar to Schedule
Demand levels not metered for Scheduleare
customers.Schedule 7 customers are also subj ect to a
$7.50 minimum charge which includes up to 144 kWh of
energy use.Similar to Schedule 1, all energy-, demand-
and customer-related costs are recovered through the
Energy Charge.Approximately 27 percent of the total
billings for Schedule 7 in the 1993 test year were
minimum bills representing approximately 5 percent of the
total class revenue.
BRILZ, Di
Idaho Power Company
What requirementtherevenue
recovered from Small General Service customers taking
service under Schedule 7?
Based on Mr. Gales I s Exhibit No.4 6, the
total annual revenue to be collected from Schedule 7
customers is $14,656,042.
Please describe the rate design proposal
for Schedule
The rate design proposal for Schedule 7 is
included on page 3 of Exhibit No. 36.The $7.50 minimum
charge has been replaced by a $2.75 customer Charge.The
$2.75 Customer Charge represents approximately 15 percent
of the cost-of-service result of $20.21 shown at line 360
on page 2 of Exhibit No.3 5.The Energy charge remains
flat and is increased from 5 .1994~ per kWh to 6. 0146~ per
kWh.
What is the impact of this rate design on
Small General Service customers?
Page 2 of Exhibit No. 37 shows the billing
comparison between the existing rates and rate structure
and the proposed rates and rate structure for typical
billing levels.Page 3 of Exhibit No.37 shows the
impact by . range percent change for Schedule
customers being moved to Schedule 7.In total,360
Schedule 33 customers qualify for Schedule Of this
BRILZ, Di
Idaho Power Company
total, approximately 56 percent receive a decrease in
their annual billing under the proposed Schedule 7 rates
compared to the existing Schedule 33 rates.
NON-METERED SCHEDULES
What are the company's non-metered service
schedules?
The company'non-metered schedules are
Dusk Dawn Customer Lighting,Unmetered General
Service, Municipal Street Lighting Service, and Traffic
Control Signal Lighting Service, Schedules 15, 40, 41,
and 42, respectively.
What is the present rate structure for Dusk
to Dawn customer Lighting on Schedule 15?
Customers taking service under Schedule 15
are charged on a per lamp basis.The Company began a
program in 1990 to convert all mercury vapor lights being
served under Schedule 15 to high pressure sodium vapor or
metal halide lights. As a result, lamps currently served
under Schedule 15 include 100, 200, and 400 watt high
pressure sodium vapor area lighting, 200 and 400 watt
high pressure sodium vapor flood lighting, and 400 and
000 watt metal halide flood lighting. Under Schedule
15, customers pay a Facilities Charge of 1.75 percent for
all new facilities required for service.
What requirement totherevenue
BRILZ, Di
Idaho Power Company
recovered from customers taking service under Schedule
15?
Based on Mr. Gales's Exhibit No. 46, the
annual revenue to be recovered from Schedule 15 customers
is $893,254.
Please describe the rate design proposal
for Schedule 15.
The rate design proposal for Schedule 15 is
included on page 7 of Exhibit No. 36.The monthly charge
for each lamp is simply decreased on a uniform percent
basis consistent with the overall 40 percent decrease for
the class as a whole.
What is the present rate structure for
Unmetered General Service under Schedule 4
customers taking service under Schedule 40
pay a flat Energy Charge based on estimated usage.
Demand- and customer-related costs are recovered through
the Energy Charge.The minimum bill for service under
Schedule 40 is $1.50 per month.
What requirementtherevenue
recovered from customers taking service under Schedule
40?
Based on Mr. Ga les I s Exhibit No.4 6, the
annual revenue to be recovered from Schedule 40 customers
is $246,427.
BRILZ, Di
Idaho Power Company
Please describe the rate design proposal
for Schedule 40.
The rate design proposal for Schedule 40 is
included on page 13 of Exhibit No. 36.The Energy Charge
remains flat and decreases from 6. 22~ per kWh to 5. 62~
per kWh
What is the present rate structure for
Municipal Street Lighting Service , Schedule 41?
Charges for Municipal Street Light~ng
Service are based on a per lamp or per pole basis.
Municipal Street lighting is divided into two types:
company-Owned and 2) customer-Owned.Schedule 41 does
not allow new service for incandescent, mercury vapor, or
fluorescent fixtures. Underground circuits are installed
this schedule the customer pays monthly
Facilities Charge 1.75 percent times the cost
difference between overhead and underground installation
charges.
What requirement totherevenue
recovered from customers taking service under Schedule
41?
Based on Mr. Gales's Exhibit No. 46, the
annual revenue requirement for Schedule 41 is $1,494,796.
Please describe the rate design proposal
for Schedule 41.
BRILZ, Di
Idaho Power Company
The rate design proposal for Schedule 41 is
included on pages 14 and of Exhibit No. 36.The
monthly charge for each lamp is simply decreased on a
uniform percent basis consistent with the overall 10
percent decrease for the class as a whole.
What is the present rate structure for
Traffic Control Signal Lighting Service, Schedule 42?
The charges f or service under Schedule 42
are based on the wattage of the lamp in the signal and
the average daily burning hours.There are no minimum
bills nor customer charges on this schedule.
What revenue requirementthe
recovered from customers taking service under Schedule
42?
Based on Mr. Gales's Exhibit No. 46, the
annual revenue requirement for Schedule 42 is $184,868.
Please describe the rate design proposal
for Schedule 42.
The rate design proposal for Schedule 42 is
included on page 16 of Exhibi t No.The monthly36.
charge for each lamp is simply decreased on a uniform
percent basis consistent with the overall 5 percent
decrease for the class as a whole.
DEMAND-METERED SCHEDULES
What the Company I S demand -meteredare
BRILZ, Di
Idaho Power Company
schedules?
The Company's demand-metered schedules are
Large General Service , Large Power Service, Irrigation
Service, and Public Water supply and Sewage Treatment,
Schedules 9, 19, 24, and 33, respectively.
What are the current eligibility criteria
for Schedules 9 and 191
Customers who have usage which equals or
exceeds 3,000 kWh a month for three or more months and
which does not exceed 750 kilowatts (kW) three or more
times during the Annual Review Period qualify for service
under Schedule 9 Customers whose usage equals
exceeds 750 kW three or more times during the Annual
Review Period qualify for service under Schedule 19.
Is the Company proposing to change the
criteria for eligibility under Schedules 9 and 19?
Yes.The Company is proposing to change
the usage level for eligibility from 750 kW to 1,000 kW.
Under the Company ' s revised eligibility criteria, the
ceiling for eligibility under Schedule 9 will change from
750 kW to 000 kW.Likewise threshold forthe
eligibility under Schedule 19 will change from 750 kW to
000 kW.
Why is the Company proposing to raise the
threshold from 750 kW to 1,000 kW?
BRILZ, Di
Idaho Power Company
The proposing raise theCompany
threshold for a number of reasons.First, as customers
electric loads have grown over the years, 750 kW has
ceased to represent a reasonable usage level to qualify
a customer as a large power user.In addition, the
requirement that a customer using 750 kW enter into
contract with the Company as a condition of receiving
service is no longer practical;750 kW is simply too
small a load to require a contract.Second, 1,000 kW is
common threshold found in most utility tariffs.
Setting the threshold at 1,000 kW will establish a
threshold more consistent with the requirements of other
utilities in the region.
Is the Company proposing any other changes
in the eligibility criteria for Schedules 9 and 19?
No.The Company is not planning to change
any other eligibility criteria based on usage.However,
the Company is planning to add Secondary, Pr imary, and
Transmission Service levels to both Schedule and
Schedule Customers will served under the19.
appropriate service level based on the voltage at the
customer I s point of delivery.
Would you please define Secondary, Primary,
and Transmission Service?
Secondary Service is service taken at 480
BRILZ, oi
Idaho Power Company
vol ts less,or where the definitions of Primary
service and Transmission Service do not apply.pr imary
service is service taken at 12,500 volts or 34,500 volts.
Transmission Service is service taken at 44,000 volts or
higher.
Why is the Company proposing to add service
levels to Schedules 9 and 19?
The Company is proposing to add service
levels for several First the costsreasons.
providing service are associated with the voltage level
at which service is received.For example, customers
receiving service at transmission voltage do not impose
the same distribution-related costs on the company'
system that customers recei ving service pr imary
voltage impose.As a result,the pr ices charged to
Transmission service should reflect thecustomers
differences in costs.The company's current practice of
giving high voltage customers a credit on their billed
demand does not adequately reflect the differences in the
costs providing service tr ansmiss ion versus
distribution voltage.By establishing service levels
based on voltage, prices can be established which more
accurately and fairly reflect the costs of providing
service.
Second, establishing voltage based service
BRILZ, Di
Idaho Power Company
levels will improve the company s ability to provide
service to customers both from an administrati ve and
customer service perspecti ve.line extensionAny
payments or facilities beyond the point of delivery will
be determined at the time service is established.There
will be no need for any adjustments or refunds at a later
date should the customer subsequently qualify for a
different schedule.As a result, transitions between
Schedules 9 and 19, as customers ' loads change, will be
simplified since customers will move to the same service
level under the appropriate schedule.
Finally,vol tage based service levels,
coupled with a cost-of-service aligned revenue allocation
to the classes, should reduce the wide discrepancy in
prices now experienced by customers who transfer between
Schedules 9 and 19.
How will customers currently taking service
under Schedule 9 and Schedule 19 be classified as either
Secondary, Primary, or Transmission Service customers?
Customers currently taking service under
Schedule will classif ied Secondary Service
customers.The 41 current Schedule 19 customers who no
longer qualify for service under that schedule with the
000 kW threshold will be classified as Schedule 9
Primary Service customers.There are no customers at
BRILZ, Di
Idaho Power Company
this time who will qualify for Schedule 9 Transmission
Service.The five Schedule 19 customers who currently
are receiving service at 44,000 volts or higher will be
classified as Schedule 19 Transmission Service customers.
All remaining Schedule 19 customers will be classified as
Pr imary Service customers.No customers qualify at this
time for Schedule 19 Secondary Service.
What is the present rate structure for
Schedule 9?
Customers taking service under Schedule 9
pay both an Energy Charge and a Demand Charge for the
metered usage.In addition, Schedule 9 customers are
subject to a $15.00 minimum charge.Approximately two
percent of the total billings for Schedule 9 during the
1993 test year were minimum billings representing about
one-half of one percent of the total class revenue.
What is the present rate structure for
Schedule 19?
Customers taking service under Schedule 19
pay an Energy Charge Demand Charge,and a Basic
Charg e .The Energy Charge is applied to the actual
metered energy for the billing period.The Demand Charge
is applied to the metered demand; however, the minimum
billing demand is 750 kW.The Basic Charge is applied to
the Basic Load Capacity which is the average of the two
BRILZ, Di
Idaho Power Company
highest billing demands during the current 12-month
period but not less than 750 kW.In addition, customers
pay a Facilities Charge of 1.7 percent per month on any
Company-owned facilities beyond the point of delivery.
Please describe the rate design proposal
for Schedule
In addition to raising the ceiling for
service eligibility from 750 kW to 1,000 kW and to
creating Secondary, Primary,and Transmission Service
levels, the Company is proposing to add a Customer Charge
and a Basic Charge to Schedule For customers taking
Primary Service or Transmission Service , a Facilities
Charge of 1.7 percent is also being added.The rate
design proposals for Schedule 9 are shown on pages 4
through 6 of Exhibit No. 36.
What is the Customer Charge for Schedule 9?
The Customer Charge for Secondary Service
under Schedule 9 is $5.50.This amount represents
approximately 15 percent of the cost-of-service result of
$35.81 shown at line 420 on page 3 of Exhibit No. 35.
The customer Charge for Primary and Transmission Service
is $85.This amount is the same charge established for
Schedule 19 Primary Service and Schedule 19 Transmission
Service reflects the cost associated with theand
electronic metering of customers at these voltage levels.
BRILZ, Di
Idaho Power Company
What is the company's proposal for adding
a Basic Charge to Schedule 9?
The is proposing that BasicCompany
Charge to be applied to each kW of Basic Load Capacity be
added to Schedule
What is Basic Load Capacity?
Basic Load Capacity is a demand-related
billing component which is computed at the time the
customer s bill is prepared by averaging the two highest
non-zero billing demands during the 12-month period
ending with the current billing period.
What is the Basic Charge for Schedule 91
The Basic Charge for Secondary Service is
36 per kW of Basic Load Capacity.The $ . 36 charge
reflects the cost of service for distribution lines and
transformers as shown at line 420 on page 3 of Exhibit
No. 35.For Primary Service, the Basic Charge is $.
per kW of Basic Load Capacity.The Basic Charge for
Transmission Service is $.39.The Basic Charge for
Primary Service and the Basic Charge for Transmission
Service are the same as those for Schedule 19.The
derivation of the $.76 and $.39 charges is detailed later
in my discussion of the Schedule 19 rate design.
What is the Demand Charge for Schedule 9?
The Demand Charge for Secondary Service is
BRILZ, Oi
I daho Power Company
decreased from $3.22 to $3.13 per kW.For pr imary
Service, the Demand Charge is $3.04 per kW.The Demand
Charge for Transmission Service is $2.95 per kW.Again,
the charges for Secondary,primary,and Transmission
service are the same as those for Schedule 19 and are
detailed in my discussion of the Schedule 19 rate design.
What is the Energy Charge for Schedule 9?
The Energy charge for Secondary Service is
decreased from 2.93460 to 2.61550 per kWh.For Pr imary
Service,the Energy Charge is 2.14900 per kWh.The
Energy Charge for Transmission Service is 2.10110 per
kWh.
How were the Energy Charges derived?
The Energy Charge for Secondary Service was
derived to recover the residual revenue requirement once
the customer, Basic, and Demand Charges were established.
The Primary service Energy Charge is set at 5 percent
over the Schedule 19 Pr imary Service Energy Charge.The
Transmission service Energy Charge is set equal to the
Schedule 9 Primary service Energy Charge adjusted to
reflect the losses avoided taking service
transmission voltage.
Why was the primary Service Energy Charge
set at 5 percent over the Schedule 19 Primary Service
Energy Charge?
BRILZ, Di
Idaho Power Company
The Company wants to ensure that a price
signal given customers there imi ted
incentive to use additional energy in order to qualify
for Schedule 19.The Energy Charge was set at 5 percent
over the Schedule 19 Primary service Energy Charge to
provide differential prices the twobetween
schedules which, when considered with the minimum Billing
Demand and Basic Load Capacity provisions under Schedule
19, provides the appropriate price signal.
What provision for a Facilities Charge is
included in your rate design proposal for Schedule 9?
Customers taking Pr imary Service and
Transmission Service will be responsible for either
owning all facilities, including the transformers, beyond
the point delivery or pay ing the Company
facilities charge in the amount of 1.7 percent times the
company's investment in the facilities beyond the point
of delivery.
What requirementtherevenue
recovered from Schedule 9?
Based on Mr. Gales s Exhibit No. 46, the
total annual revenue to be collected from customers
taking service under Schedule 9 is $78 042,429.This
revenue requirement includes the revenue to be collected
from existing Schedule 33 customers moved to Schedule 9
BRILZ, oi
Idaho Power Company
as well as from existing Schedule 19 customers targeted
to be Schedule 9 Primary Service customers.
What is the impact of this rate design on
Large General Service customers?
As can be seen from page 4 of Exhibit No.
37, approximately 69 percent of the existing customers
taking service under Schedule Secondary Service)
receive a reduction in their annual bills as a result of
the proposed rate design.Of the customers receiving a
reduction, approximately 40% receive a decrease greater
than the 3.78 percent recommended by the Company for the
Secondary Service customers as a whole.
What are the usage characteristics of the
Secondary Service recei ving andcustomersdecreases
increases under your proposal?
Page 4 of Exhibit No.3 7 shows the average
load factor for customers in each "percent range " group.
As can be seen from this Exhibit , the percent decrease or
increase received through the rate design is associated
wi th the customer's load factor.specifically, customers
whose monthly demand remains fairly steady and close to
the Basic Load capacity will tend to receive a decrease
in their annual billings.Conversely, customers whose
monthly demand throughout the year varies relatively
widely from the Basic capaci ty will generallyLoad
BRILZ, Di
Idaho Power Company
receive an increase in their annual billings.Examples
of the usage characteristics customers receiving
decreases and increases under the rate design proposed
are included in my workpapers.
What is the impact of your rate design
proposal on customers transferring from Schedule 33 to
Schedule 9?
All customers transferring from Schedule 33
to Schedule 9 will be served at Secondary Service.Page
5 of Exhibit No. 37 shows the impact of the proposed rate
design by range of percent change.As can be seen from
this Exhibit, approximately 45 percent of the Schedule 33
customers receive a decrease in their annual billing
under the Schedule 9 rate design.Of the remaining 226
customers who receive an increase under Schedule 9, 52
percent receive an increase of less than 5 percent, which
is the overall class increase which would be required to
bring the existing Schedule 33 customers to cost of
service as shown on Mr. Gales' Exhibit No. 46.
What is the impact of your rate design
proposal customers taking Pr imary Service under
Schedule 9?
Page 6 of Exhibi t No.3 7 shows the impact
of the rate design proposal on Primary Service customers
by range of percent change.Page 7 of Exhibit No. 37
BRILZ, Di
Idaho Power Company
shows the impact of the rate design proposal on each
Primary Service customer.compared to the existing
Schedule rates,the proposed Schedule 9. pr imary
Service rates result in an increase in annual billings
for all but one customer.Page 8 of Exhibit No. 37 shows
the impact of the rate design proposal compared to the
proposed rates for Schedule 19 Primary Service.As can
be seen on page 8 of Exhibit No. 37, all but 5 customers
have lower annual bills under the proposed Schedule 9
Primary Service than under the proposed Schedule
Primary Service.Page 9 of Exhibit No.3 7 shows the
impact of the proposed rate design compared with the
proposed Schedule 19 Primary Service rate design by
individual customer.
What design proposal fortherate
Schedule 19?
In addition to raising the threshold from
750 kW to 1,000 kW and adding Secondary, Primary, and
Transmission Service levels to Schedule 19, a CUstomer
Charge is being added. There are no other changes in rate
structure proposed for Schedule 19.The rate design
proposals are shown on pages 8 through 10 of Exhibit No.
36.
What is the Customer Charge for Schedule
19?
BRILZ, Di
Idaho Power Company
For Primary and Transmission Service the
Customer Charge is $85.Eighty-five dollars reflects
approximately 30 percent of the $292.74 amount supported
by cost of service as shown at line 480 on page 4 of
Exhibit No.For Secondary Service,the Customer35.
charge is $5.50.This amount is the same as that for
Schedule 9 Secondary Service.
You stated earlier that one of the pricing
objectives of your rate design proposal was to establish
the Customer Charge at 15 percent of cost of service.
Why are you proposing the Customer charge be set at 30
percent for primary and Transmission Service?
All of the customers who will be classified
as Primary and Transmission Service customers under
ei ther Schedule 9 or Schedule 19 are currently taking
service under Schedule 19.These customers are among the
Company's "largest and most sophisticated users.
placing more emphasis on the Customer Charge for this
group of customers , the Energy Charge and Demand Charge
can be set closer to cost of service than they otherwise
would be, thus benef tting the most efficient customers.
What is the Basic Charge for Schedule 19?
The Basic Charge for Secondary Service is
36, the same as that for Schedule 9 Secondary Service.
For Primary Service,the Basic charge is $.76 whicJ1
BRILZ, Di
Idaho Power company
reflects the cost of service for distribution facilities
as shown at line 480 on page 4 of Exhibit No. 35.For
Transmission Service the Basic Charge is $.39.Again,
this represents the cost service forcharge
distribution facilities used to serve customers taking
service at transmission voltage.
What is the Demand Charge for Schedule 19?
The Demand Charge for Primary Service is
$3.04.This Demand Charge was computed to recover the
residual revenue requirement once the Customer, Basic,
and Energy Charges were determined.For Transmission
service the Demand Charge is $2.95.This Demand Charge
was derived by deducting from the $3.04 Primary Service
Demand Charge the losses which are avoided by service
being taken at the transmission level.The Demand Charge
for Secondary Service is $3.13 which was derived by
adding to the $3. 04 Pr imary Service Demand Charge losses
incurred by service being taken at secondary vol tage.
Consistent with increase threshold forthethe
eligibility from 750 kW to 1,000 kW, the minimum billing
demand is also increased from 750 kW to 1,000 kW.
What is the Energy Charge for Schedule 19?
The Energy Charge for Pr imary Service
remains unchanged from its current level of 2.04670.The
Energy Charge for Transmission Service is 2.00110 per
BRILZ, Di
Idaho Power Company
kWh.This amount reflects an adjustment to the 2. 0467C
to take into account the losses which are avoided by
service being taken at transmission voltage.The Energy
Charge for Secondary Service is set at the Schedule 9
Secondary Service Energy charge less 4.75 percent to
reflect the same degree of difference in Energy Charges
as is established for Schedule 9 Primary Service and
Schedule 19 Primary Service.
Does your rate design proposal include any
revisions to the provision for a Facilities Charge under
Schedule 19?
No.Customers taking Pr imary Service and
Transmission Service will continue to be required to
either own all facilities , including transformers, beyond
the point of delivery or pay the Company a Facilities
Charge of 1.7 percent times the Company's investment in
those facilities.Customers taking Secondary Service
will not be subject to a Facilities Charge.
What tot a I annual revenuethe
requirement to be collected from Large Power Service
customers?
Based on Mr. Gales s Exhibit No. 46, the
total annual revenue requirement to be collected from
Schedule 19 is $44,860,097.
What is the impact of the rate design on
BRILZ, Di
Idaho Power Company
Large Power Service customers?
Pages 10 through 12 of Exhibit No. 37 show
the impact the rate design for Primary service
customers.the Schedule Pr imary Service
customers, receive increase less than
percent, which is the overall increase for the Primary
service customer group as a whole.The impact on the
Schedule 19 Transmission Service customers is detailed on
page of Exhibit No.Of the five customers37.
receiving Transmission Service, two receive an increase
less than the overall increase for the group of 5.
percent.
What are the usage characteristics of the
customers receiving increases less than and greater than
the overall increases for the respective groups as a
whole?
general,Pr imary and Transmission
Service customers who have monthly billing demands which
remain fairly steady and close to the Basic Load capacity
tend to have less of an increase in their annual billing
than do customers whose monthly demand throughout the
year varies from the Basic Load Capacity.Also, because
the rate design proposal places an increased emphasis on
capacity, the higher the customer' s load factor, the more
beneficial the rate structure tends to be in terms of the
BRILZ, oi
Idaho Power Company
overall increase to the annual billing.
What is the current rate structure for
Schedule 24?
Service under Schedule 24 is classified as
being either " in-season" or lI out-of-season"The in-
season for each customer begins with the customer's meter
reading for the May billing period and ends with the
customer'meter reading the September billingfor
period.The out-of-season encompasses all other billing
periods.
wi thin the in-season, customers pay both an
Energy Charge and a Demand Charge for the metered usage.
During the out-of-season, customers pay an Energy Charge
only.For both the in- and out-of-season, customers are
subject to a $15.00 minimum charge.Approximately
percent of the total billings for Schedule 24 during the
1993 test year were minimum billings representing about
four-tenths of one percent of the total class revenue.
Please describe the rate design proposal
for Schedule 24.
As with the other demand-metered schedules,
the Company is proposing to add a Customer Charge and a
Basic Charge to Schedule 24.In addition, the Company is
proposing to add Secondary and Transmission Service
levels to Schedule 24.The proposed rate designs for
BRILZ, Di
Idaho Power Company
Schedule 24 are shown on pages 11 and 12 of Exhibit No.
36.
Are the def ini tions for Secondary Service
and Transmission Service for Schedule 24 the same as
those for Schedules 9 and 19?
Yes.Secondary Service is service taken at
480 volts less,where the def ini tion
Transmission Service not apply.Transmissiondoes
Service is service taken at 44,000 volts or higher.
Why is the Company proposing to add service
levels to Schedule 24?
As stated earlier in my testimony,the
costs of providing service are associated wi th the
voltage level which service recei ved.
establishing service levels based on voltage, prices can
be established which more accurately and fairly reflect
the costs of providing service.
How.will customers currently taking service
under Schedule 24 be classified as either Secondary or
Transmission Service customers?
The two customers who currently recei
service at 44,000 volts or higher will be classified as
Transmission Service customers.All other Schedule 24
customers will classif ied Secondary Service
customers.
BRILZ, Di
Idaho Power Company
What is the Customer Charge for Schedule
24?
The Customer charge for Secondary Service
is $10.This amount represents approximately 15 percent
of the cost-of-service result of $67.08 as shown at line
540 on page 5 of Exhibit No. 35.The Customer Charge for
Transmission Service is $85.This amount is the same
charge established Schedule and Schedulefor
Transmission Service.
What is the Company's proposal for adding
a Basic Charge to Schedule 24?
The propos ing BasicthatCompany
Charge, to be applied on an annual basis to each kW of
Basic Load Capacity, be added to Schedule 24.
How is Basic Load Capacity calculated for
Schedule 24?
Similar the Basic capaci tyLoad
calculation for both Schedules 9 and 19, the Basic Load
Capacity for Schedule is computed by taking the
average of the two highest non-zero billing demands
during a twelve month period.However, unlike Schedules
9 and 19 where the Basic Load Capacity is computed and
billed each month using a rolling 12-month period, the
Basic Load Capacity for Schedule 24 is computed for the
12-month period beginning with the customer's November
BRILZ, Di
Idaho Power Company
billing period.addition,Basic fortheCharge
Schedule 24 is not billed on a regular monthly basis.
How Basic billed undertheCharge
Schedule 24?
Each month when a customer's monthly bill
is prepared, the Basic Load Capacity is calculated by
taking the average of the two highest non-zero monthly
metered demands for the 12-month period beginning with
the customer'November billing period.theFor
customer's first bill prepared for the 12-month period,
the Basic charge is applied to 50 percent of the Basic
Load Capacity.For each subsequent bill during the 12-
month period,Basic applied thetheCharge
difference between the Basic Load Capacity computed at
the time the current bill is prepared and the Basic Load
Capacity against which the Basic Charge has already been
applied.In this way, a true-up is made on a monthly
basis, if necessary, to collect the Basic Charge on all
kW of Basic Load capacity on an annual basis.An example
of how the Basic Charge is applied is included in my
workpapers.
What is the Basic Charge for Schedule 24?
The Basic Charge for Secondary Service is
$5.45.Although cost of service supports a Basic Charge
of $13.84 as shown at line 540 on page 5 of Exhibit No.
BRILZ, Di
Idaho Power Company
35, the Company desired to cap the amount of revenue to
be derived from the Basic Charge at 8 percent of total
overall revenue for the class.The $5.45 Basic Charge is
a result of this cap.The Basic Charge for Transmission
Service is $1.72.This amount was computed by applying
the ratio $5.45,the proposed Basic forCharge
Secondary service, to $13.84, the Basic Charge supported
by cost of service, to $4.37, the Transmission Service
Basic Charge supported by cost of service ($4,095,116
(line 503, page 5, Exhibit No. 35) + 937,854 kW (line
505, page 5, Exhibit No. 35)).
What is the Demand Charge for Schedule 24?
The Demand Charge for Secondary Service is
increased from $2.69 to $3.13 per kW.The Demand Charge
for Transmission Service is $2.95.These charges are the
same as the Secondary and Transmission Service Demand
Charges for Schedules 9 and 19.The Demand Charge is
billed to Schedule 24 customers during the in-season
only.
What is the Energy Charge for Schedule 24?
The Energy Charge for Secondary Service is
increased from 2.68459 per kWh to 2.83979 per kWh during
the in-season and from 3.41729 per kWh to 3.61479 per kWh
during the out-of-season.These charges were increased
by a uniform percentage to recover the residual revenue
BRILZ, Di
Idaho Power Company
requirement once the customer, Basic, and Demand Charges
were established.The Energy Charge for Transmission
Service is increased from 2. 6845Q per kWh to 2. 6988Q per
kWh during the in-season and from 4172Q per kWh to
4353Q per kWh for the out-of-season.The Transmission
service Energy Charges were derived by adjusting the
Secondary Service Energy Charges for the losses avoided
by service being taken at transmission voltage.
What provision for a Facilities Charge is
included in your rate design proposal for Schedule 24?
Customers taking Transmission Service will
responsible either owning facilities,allfor
including the transformers , beyond the point of delivery
or paying to the Company a Facilities Charge in the
amount of 1. 7 percent times the Company I s investment in
the facilities beyond the point of delivery.
What is the impact of the rate designs on
Irrigation Service customers?
As can be seen from page 14 of Exhibit No.
37,approximately 16 percent of the customers taking
service under Schedule 24 receive an increase in their
annual bills of less than 18 percent, the total overall
percentage increase for the class as a whole.Another 14
percent of the customers receive an increase of just 3
percent or less above the overall class increase of 18
BRILZ, Di
Idaho Power Company
percent.Page 15 of Exhibit No. 37 details the impact of
the rate design two Transmission servicethe
customers.
What are the usage characteristics of the
Schedule 24 customers receiving increases less than and
greater than 18 percent?
general,case with boththe
Schedule and Schedule customers Schedule
customers who have monthly billing demands which remain
fairly steady and close to the Basic Load Capacity tend
to have less of an increase in their annual billing than
do customers whose monthly demand varies from the Basic
Load Capacity.Also, because the rate design places an
increased emphasis on capacity, the higher a customer I s
load factor, the more beneficial the rate structure tends
to be in terms of the overall increase to the annual
billing.
SPECIAL CONTRACT CUSTOMERS
What the Company I S rate designare
proposals for its special contract customers?
The Company is not proposing any changes at
this time to the rate structures for the four special
contract customers:Micron Semiconductor,FMC
Corpor a t i on,Simplot and DOE/INEL.Company,
Accordingly, the existing rates for the special contract
BRILZ, Di
Idaho Power Company
customers are simply increased uniformly to recover the
revenue requirement as shown on Mr. Gale s Exhibit No.
46.The rates for Micron,Simplot,andFMC
DOE/INEL are shown on pages 17 , 18, 19, and 20 of Exhibit
No. 36, respectively.
STANDBY AND ALTERNATE DISTRIBUTION SERVICE
What are the revisions being proposed for
Schedule 45, Standby Service?
In Order No. 22887 issued in Case No. IPC-
E-89-4, in which Schedule 45 was initially adopted, the
commission approved a Standby Reservation Charge of $.
per kW while recognizing that this charge was not cost-
based and did not include any component for generation or
transmission.commission required theThefurther
Company lito establish and document all related costs
(including generation and transmission) in its next cost
of service or general ratemaking proceeding (Page 8).
At this time, the Company is proposing the adoption of a
cost-based Standby Reservation Charge which recognizes
generation,transmission,distribution costsand
associated with providing Standby Service.
Have you prepared an exhibit showing the
derivation of the proposed charges for standby Service?
Yes, I have.Exhibit No. 40 details the
deri vat ion of the proposed charges.
BRILZ, Di
Idaho Power Company
What methodology was used to determine the
proposed standby Reservation Charge?
The Rationale Approach ( Zakem,Reserve
J., "Principles of standby Service , Public utilities
Fortnightly (November 1988)) ,which recognizes the
utility'reserve margin,was used to determine the
generation capacity reserve component of the standby
Reservation determine appropriatetheCharge.
generation capacity reserve component, I calculated a
weighted operating reserve margin of 5.8 percent using
the Northwest Power Pool Operating Committee' s Minimum
operating Reserve of 5 percent for hydro generation and
percent for thermal generation and the installed
capaci ty of each of the company' s plants as reported in
FERC Form I applied the 5.8 percent weighted reserve
margin to the $1.81 unit cost for Schedule 19 Production
demand shown at line 429 on page 4 of Exhibit No. 35 to
obtain a generation capacity reservation charge of $ .
per kW.
determine transmission capaci tythe
reserve component, I used an Equivalent Forced outage
Rate (EFOR) of 10 percent since, with just one customer
taking Standby Service, a reliable actual forced outage
rate is not available.The EFOR represents a proxy for
the likelihood that the standby customer will be taking
BRILZ, Di
Idaho Power Company
service at the time of the system peak.A 10 percent
EFOR selected since this thefactorwas
conservative end of the 10 percent to 20 percent range
most commonly used by utilities in the united states
(Casazza,Schul tz & Associates,"Standby RateInc. ,
Survey and Analysis Final Draft Report"March 6 , 1990).
applied percent EFOR to the sum of thethe
Transmission demand unit costs of $.88 and $.31 for
Schedule 19 shown at lines 437 and 438 on page 4 of
Exhibi t obta in transmission capaci tyNo.
reservation charge of $. 12 per kW.
The distribution facili ties in place to
serve a standby customer are sized to meet the standby
requirements of the customer and are in place, ready to
provide service,at all times.The distribution
capaci ty reservation component,therefore,should be
based on 100 percent of the capacity-related distribution
costs.determine distr ibution capaci tythe
reservation component,simply took the sum of the
Distribution demand revenue requirement for Substations
Primary Lines, and Primary Transformers for Schedule 19
shown at lines 443, 445, and 448 on page 4 of Exhibit No.
35 ($1,239,598; $2,531,966; and $261,093, respectively)
and divided this sum by the total billed kW of 3,210,055.
The resultant distribution capacity reservation component
BRILZ , Di
Idaho Power company
is $1.26 for service taken at primary voltage.For
service taken at transmission voltage,the resultant
distribution capacity reservation component is $.39.
What standby Reservation Chargethe
proposed for Schedule 45?
The standby Reservation Charge is the sum
the generation,transmission,distributionand
components I just described.For Pr imary Service the
charge is $1.48 per kW.
charge is $.61.
For Transmission Service the
Are there other madeanychanges
Schedule 45?
Yes.The definition Supplementary
Billing Demand is revised to reflect the threshold of
000 kW under Schedule 19.In addition, the Monthly
Charge section revised the standbyreflect
Reservation Charge and the Standby Demand Charge for both
primary and Transmission Service.
What are the Standby Demand Charges?
For Pr imary service the Standby Demand
Charge is $3.82 per kW.This charge was derived by
multiplying the Schedule 45 total demand component of
$4.26, shown at line 10 on Exhibit No. 40, by the ratio
of the Schedule 19 Primary Service Demand Charge of $3.
to the cost-of-service amount of $3.39 as shown at line
BRILZ, Di
Idaho Power Company
480 on page 4 of Exhibit No. 35.The Standby Demand
Charge for Transmission Service is $3.70 which reflects
the $3.82 Primary service Standby Demand Charge reduced
f or losses.
What changes are made Schedule 46,
Alternate Distribution Service?
The current Capacity Charge for Schedule 46
is $.59 per kW.As stated by the Commission in the
adoption of this charge in Order No. 22887 in Case No.
IPC-E-89-4, this charge reflects distribution substation
capacity costs and distribution line capacity costs.The
Company is proposing to update the Capacity Charge to
$1. 26 to reflect the current costs of providing Alternate
Distribution Service.The $1.26 amount is derived by
summing the Distribution demand revenue requirement for
Substations, Primary Lines, and Primary Transformers for
Schedule shown Exhibi t No.page
($1,239,598; $2,531,966; and $261,093, respectively) and
dividing this sum by the total billed kW of 3,210,055.
Are any customers currently taking service
under Schedule 46?
No.There are no customers taking service
under Schedule 46 at this time.
IMPLEMENTATION PLAN
What Company I S plan for thethe
BRILZ, Di
Idaho Power Company
implementation of the revised rate structures?
For all service schedules,the
implementation Customer Charge madethecan
immediately upon issuance of the Commission I s Order in
this proceeding.The revised Energy Charge for both
Schedule 1 and Schedule 7 , as well as the revised charges
for non-metered Schedules 15, 40, 41, and 42, can also be
implemented upon issuance of the Commission I s Order.
Additionally, the elimination of Schedule 33 and the
transfer of the customers taking service under that
schedule to ei ther Schedule 7 or Schedule 9 can be
implemented immediately.The implementation of the
service levels for Schedules 19,and the24,
implementation of the 1,000 kW threshold for Schedules 9
and 19, and the implementation of the Basic Charge for
Schedules 9 and 24, however, need to be delayed to allow
the Company I S billing modifiedsystem
accommodate the revisions.
What is the implementation schedule for
Schedules 9, 19, and 24?
The Company proposes that the revisions to
add service levels to Schedules 9 and 19 and the revision
to add the Basic Charge to Schedule 9 be implemented
within 14 weeks after the issuance of the Commission I
Order. At the time of implementation, the Secondary,
BRILZ, Di
Idaho Power Company
Pr imary ,and Transmission Service customers will
determined and will be established on the appropriate
schedule at the appropriate service level.The revisions
to Schedule 24 to add service levels and the Basic Charge
are proposed to be implemented beginning with each
customer's meter reading for the November, 1995 billing
period.Implementing the revisions to Schedule
coincident with each customer's November meter reading
will eliminate the need to prorate customer's bills and
will also allow a consistent rate structure to be
place for the entire irrigation season.In addition, a
November implementation will minimize the number
customers immediately affected by the rate design since
most irrigation customers will be disconnected from the
Company's system at that time.
What Company propos ing thethefor
interim period between issuance of the Commission's order
and implementation of the rate design?
The Company is proposing to implement an
interim rate design for each of the three schedules which
is consistent with the objectives of what I will call the
"final" rate design.
What is the interim rate design proposal
for Schedule 9?
The inter im design proposal forrate
BRILZ, Di
Idaho Power Company
Schedule 9 is shown on page 2 of Exhibit No. 41.
shown on this Exhibit, the Customer Charge is $5.50.The
Demand Charge is $3.59.The Energy Charge is 2. 6160~ per
kWh, adjusted slightly from the Energy Charge of 2. 6155~
proposed for the final rate design in order to recover
the revenue requirement.The percent of revenue der i ved
from the customer,demand,and energy components is
identical for both the interim and final rate designs.
What impact does the interim rate design
have on Schedule 9 Secondary Service customers?
As can be seen from page 1 of Exhibit No.
42,the impact on customers I annual bills under the
interim rate design is nearly identical to the impact on
customers I annual bills under the final rate design.
Page 2 of Exhibit No. 42 shows the impact on customers'
annual bills of the implementation of the final rate
design compared to the interim rate design.As can be
seen from page 2, there is little impact on Schedule 9
customers I annual bills as a result of moving from the
interim to the final rate design.Page 3 of Exhibit No.
42 shows the impact of the interim rate design on the
Schedule 33 customers transferred to Schedule 9.As can
be seen from page 3, the impact on Schedule 33 customers
annual bills as a result of the interim rate design is
nearly identical to that of the proposed rate design.
BRILZ, Di
Idaho Power Company
Page 4 of Exhibit No. 42 shows the impact on Schedule 33
customers I annual bill of the implementation of the final
rate design compared to the interim rate design.Again,
there is little impact on Schedule 33 customers I annual
bills as a result of moving from the interim to the final
rate design.
What is the interim rate design proposal
- for Schedule 19?
Because Schedule 19 already provides for a
Basic Charge, the only final rate design provision which
must be delayed is the addition of service levels.As a
result, the customer, Basic, Energy, and Demand Charges
proposed for the final rate design can be implemented
immediately upon approval.The only revision to the
final rate design which must be made during the interim
is the retention of the High Voltage Credi t and the
adjustment of this charge from $.59 per kW to $.75 per kW
to reflect the percentage change to the Demand Charge
( $ . 59 ( (3 . 04 - 2 . 39) /2 . 39) ) ) .The interim rate(1 +
design proposal is shown on page 3 of Exhibit No. 41.
During the interim period, the Schedule 9 Primary Service
customers will remain on Schedule 19.
What is the impact on Schedule 19 customers
of the interim rate design proposal?
The impact on the existing Schedule
BRILZ, Di
Idaho Power Company
customers ' annual bills as a result of the interim rate
design proposal is nearly identical to the impact of the
final rate design.Pages 5 through 16 of Exhibit No. 42
show the impact of the interim rate design and the impact
of moving from the interim to the final rate design for
Schedule 9 Primary service customers and for Schedule 19
Primary and Transmission Service customers.
What is the interim rate design proposal
for Schedule 24?
The inter im design proposal forrate
Schedule 24 is shown on page 4 of Exhibit No. 41.
shown on this Exhibit, the Customer Charge is $10.The
Demand Charge is $4.69 per kW.The Energy Charge for the
in-season is 2.83970 per kWh.The Energy Charge f or the
out-of-season is 3.61470 per kWh.These Energy Charges
are identical to those under the final rate design.The
High Voltage Credit is retained for the interim rate
design and is adjusted from $.59 per kW tq $1.03 per kW
to reflect the percent change in the Demand Charge ($.
(1 + ((4.69 - 2.69)/2.69))).The percent of revenue
der i ved from the customer, demand, and energy components
is identical for both the interim and final rate designs.
What impact does the interim rate design
have on Schedule 24 customers?
As can be seen from page 17 of Exhibit No.
BRILZ, Di
Idaho Power Company
, the impact on Schedule 24 customers ' annual bills
under the interim rate design is nearly identical to the
impact on customers I annual bills under the final rate
design.Page 18 of Exhibit No.4 2 shows the impact on
customers of moving from the interim to the final rate
design.As can be seen from page 18, there is minimal
impact on customers' annual bills as a result of moving
from the interim to the final rate design.
Does this conclude your testimony?
Yes , it does.
BRILZ, Di
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTilITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Development of Weighted Demand and
Energy Allocation Factors
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6
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Summary of Revenue Impact and
Calculation of Proposed Rates
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0
43
4
,
62
5
91
3
,
90
7
34
8
,
53
2
25
.
16
.
82
%
DO
E
17
2
.
29
7
.
98
2
57
3
.
12
6
64
3
.
05
6
21
6
.
18
2
24
.
18
.
00
%
To
t
a
l

s
p
e
c
i
a
l

C
o
n
t
r
a
c
t
s
29
1
,
44
6
,
38
8
$4
7
,
96
7
,
02
9
$7
,
79
0
,
80
9
$5
5
,
75
7
,
83
8
24
.
16
.
24
%
To
t
a
l

I
d
a
h
o

R
e
t
a
i
l

S
a
l
e
s
29
4
,
90
4
11
,
33
9
,
28
2
,
54
2
$4
0
7
,
66
7
,
45
5
$3
7
,
05
3
,
33
4
$4
4
4
,
72
0
,
78
9
39
.
09
%
EX
H
I
B
I
T

N
O
.

CA
S
E

N
O
.

I
P
C
-
94
-
M.

B
R
I
L
Z
.

I
P
C
O
PA
G
E

1
O
F

2
0
Id
a
h
o

P
o
w
e
r

c
o
m
p
a
o
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
Re
s
i
d
e
n
t
i
a
l

S
e
r
v
i
c
e

-

S
c
h
e
d
u
l
e

1
(1
)
(2
)
(3
)
(4
)
(5
)
Li
n
e
Cu
r
r
e
n
t
Cu
r
r
e
n
t
Pr
o
p
o
s
e
d
pr
o
p
o
s
e
d
t!
Q
De
s
c
r
i
Us
e
Ra
t
e
Re
v
e
n
u
e
Ra
t
e
Re
v
e
n
u
e
Nu
m
b
e
r

o
f

B
i
l
l
s
94
5
,
68
7
.
$2
.
$7
,
36
4
,
21
9
No

o
f

M
i
n
i
m
u
m

B
i
l
l
s
12
8
,
72
6
.
$7
.
$9
6
5
,
44
6
kW
h

i
n

M
i
n
.
Bi
l
l
27
4
,
04
5
Bi
l
l
e
d

k
W
h
51
5
.
76
6
.
37
6
04
7
0
1
6
16
5
,
29
7
,
27
2
To
t
a
l

k
W
h
52
4
,
04
0
,
42
1
05
0
2
1
1
17
6
,
94
5
,
59
4
cu
s
t
o
m
e
r

A
d
j
.
48
7
48
7
To
t
a
l

B
i
l
l

i
n
9
$1
6
6
,
26
7
,
20
5
$1
8
4
,
31
4
,
30
0
EX
H
I
B
I
T

N
O
.

CA
S
E

N
O
.

I
P
C
-
94
-
M.

B
R
I
L
l
.

I
P
C
O
PA
G
E

2

O
F

2
0
Id
a
h
o

p
o
w
e
r

c
o
m
p
a
n
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
Ge
n
e
r
a
l

S
e
r
v
i
c
e

-

S
c
h
e
d
u
l
e

7
Sm
a
l
l
(1
)
(2
)
(3
)
(4
)
(5
)
Li
n
e
cu
r
r
e
n
t
cu
r
r
e
n
t
Pr
o
p
o
s
e
d
pr
o
p
o
s
e
d
f!
g
es
c
r
i
ti
o
Us
e
Ra
t
e
Re
v
e
n
u
e
Ra
t
e
Re
v
e
n
u
e
Nu
m
b
e
r

o
f

B
i
l
l
s
29
2
,
87
6
.
Sc
h
e
d
u
l
e

3
3

A
d
j
.
12
4
.
To
t
a
l

B
i
l
l
s
29
7
,
00
0
.
$2
.
$8
1
6
,
75
1
No

o
f

M
i
n
.
Bi
l
l
s
83
,
81
8
.
$7
.
$6
2
8
,
64
0
kW
h

i
n

M
i
n
.

B
i
l
l
49
0
,
55
8
Ch
a
r
g
e
a
b
l
e

k
W
h
22
2
,
51
5
,
67
6
05
1
9
9
4
11
,
56
9
,
48
0
Sc
h
e
d
u
l
e

3
3

A
d
j
.
87
0
,
40
3
To
t
a
l

k
W
h
22
6
,
38
6
,
07
9
To
t
a
l

k
W
h
22
9
,
87
6
,
63
7
06
0
1
4
6
13
,
82
6
,
16
0
cu
s
t
o
m
e
r
Ad
j
.
13
,
20
2
13
,
20
2
Sc
h
e
d
u
l
e
33

A
d
j
.
23
4
,
95
9
To
t
a
l

B
i
l
l
i
n
g
$1
2
,
44
6
,
28
1
$1
4
,
65
6
,
11
3
EX
H
I
B
I
T

N
O
.

CA
S
E

N
O
.

I
P
C
-
94
-
M.

B
R
I
L
l
.

I
P
C
O
PA
G
E

3

O
F

2
0
Id
a
h
o

p
o
w
e
r

c
o
m
p
a
n
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
La
r
g
e

G
e
n
e
r
a
l

s
e
r
v
i
c
e
Sc
h
e
d
u
l
e

9

s
e
c
o
n
d
a
r
y

S
e
r
v
i
c
e
(1
)
(2
)
(3
)
(4
)
(5
)
Li
n
e
Cu
r
r
e
n
t
Cu
r
r
e
n
t
se
c
o
n
d
a
r
y
pr
o
p
o
s
e
d
li
S
!
De
s
c
r
i
ti
o
n
Us
e
Ra
t
e
Re
v
e
n
u
e
Ra
t
e
Re
v
e
n
u
e
Nu
m
b
e
r

o
f

B
i
l
l
s
13
9
,
16
9
.
Sc
h
e
d
u
l
e

3
3

A
d
j
.
11
4
.
To
t
a
l

B
i
l
l
s
14
4
,
28
4
.
$5
.
$7
9
3
,
56
2
No

o
f

M
i
n
.
Bi
l
l
s
52
1
$1
5
.
$3
7
,
81
5
kW

i
n

M
i
n
.

B
i
l
l
19
2
kW
h

i
n

M
i
n
.
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l
l
17
5
,
88
7
Ba
s
i
c

L
o
a
d

k
W
*
09
9
,
43
8
91
5
,
79
8
kW

0

f

D
e
m
a
n
d
03
8
,
98
2
19
,
44
5
,
52
2
Sc
h
e
d
u
l
e

3
3

A
d
j
.
27
6
,
15
9
To
t
a
l

k
W
31
7
,
33
3
19
,
17
3
,
25
2
ch
a
r
g
e
a
b
l
e

k
W
h
84
5
,
01
4
,
02
9
02
9
3
4
6
54
,
14
3
,
78
2
Sc
h
e
d
u
l
e

3
3

A
d
j
.
96
,
74
2
,
42
2
To
t
a
l

k
W
h
94
1
,
93
2
,
33
8
02
6
1
5
5
50
,
79
1
,
24
0
cu
s
t
o
m
e
r

A
d
j
.
(2
7
2
,
40
9
)
(2
7
2
,
40
9
)
Sc
h
e
d
u
l
e
33

A
d
j
.
38
6
82
7
To
t
a
l

B
i
l
l
i
n
g
$7
6
,
74
1
,
53
7
$7
4
,
00
1
,
44
3
*
B
a
s
i
c

L
o
a
d

C
a
o
a
c
i
t
v
Sc
h
e
d
u

l
e

9
72
8
,
17
5
EX
H
I
B
I
T

N
O
.

Sc
h
e
d
u
l
e

3
3
Ad
j
u
s
t
m
e
n
t
37
1
,
26
3
CA
S
E

N
O
.

I
P
C
-
94
-
To
t
a
l
09
9
,
43
8
M.

B
R
I
l
l
.

I
P
C
O
PA
G
E

4

O
F

2
0
Id
a
h
o

P
o
w
e
r

C
o
m
p
a
n
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
La
r
g
e

G
e
n
e
r
a
l

S
e
r
v
i
c
e
Sc
h
e
d
u
l
e

9

P
r
i
m
a
r
y

S
e
r
v
i
c
e
(1
)
(2
)
(3
)
(4
)
(5
)
Li
n
e
Cu
r
r
e
n
t
Cu
r
r
e
n
t
Pr

i
m
a
r
y
Pr
o
p
o
s
e
d
es
c
r
i
Us
e
Ra
t
e
Re
v
e
n
u
e
Ra
t
e
Re
v
e
n
u
e
Nu
m
b
e
r

o
f

B
i
l
l
s
44
6
.
$8
5
.
$3
7
,
91
9
Ba
s
i
c

L
o
a
d

k
W
40
3
,
43
2
28
6
,
43
7
30
6
,
60
8
Bi
l
l
e
d

k
W
*
35
8
,
36
4
85
6
,
49
0
Me
t
e
r
e
d

k
W
32
3
,
10
0
98
2
,
22
4
To
t
a
l

k
W
h
12
6
,
26
3
,
65
2
02
0
4
6
7
58
4
,
23
8
02
1
4
9
0
71
3
,
40
6
To
t
a
l

B
i
l
l
i
n
g
$3
,
72
7
,
16
5
$4
,
04
0
,
15
7
*p
r
e
v
i
o
u
s

S
c
h
e
d
u
l
e

1
9

c
u
s
t
o
m
e
r
s

w
e
r
e

b
i
l
l
e
d

a

m
i
n
i
m
u
m

o
f

7
5
0

kW
,
wh
e
n

m
e
t
e
r
e
d

k
W

w
a
s

l
e
s
s

t
h
a
n

75
0
.
EX
H
I
B
I
T

N
O
.

CA
S
E

N
O
.

I
P
C
-
94
-
M.

B
R
I
L
l
.

IP
c
a
PA
G
E

5

O
F

2
0
Id
a
h
o

p
o
w
e
r

c
o
m
p
a
n
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
La
r
g
e

G
e
n
e
r
a
l

s
e
r
v
i
c
e
Sc
h
e
d
u
l
e

9

T
r
a
n
s
m
i
s
s
i
o
n

s
e
r
v
i
c
e
(1
)
(2
)
(3
)
(4
)
(5
)
Li
n
e
Cu
r
r
e
n
t
Cu
r
r
e
n
t
Tr
a
n
s
m
i
s
s
i
o
n
pr
o
p
o
s
e
d
ID
2
De
s
Us
e
Ra
t
e
ev
e
n
u
e
Ra
t
e
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v
e
n
u
e
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m
b
e
r

o
f

B
i
l
l
s
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h
e
d
u
l
e

3
3

A
d
j
.
To
t
a
l

B
i
l
l
s
$8
5
.
No

o
f

H
i
n
.

B
i
l
l
s
$0
.
kW

i
n

H
i
n
.

B
i
l
l
kW
h

i
n

H
i
n
.

B
i
l
l
Ba
s

i
c

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a
d

k
W
kW

o
f

D
e
m
a
n
d
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h
e
d
u
l
e

3
3

A
d
j
.
To
t
a
l

k
W
Ch
a
r
g
e
a
b
l
e

k
W
h
O.

0
0
0
0
0
0
Sc
h
e
d
u
l
e

3
3

A
d
j
.
To
t
a
l

k
W
h
02
1
0
1
1
cu
s
t
o
m
e
r

A
d
j
.
Sc
h
e
d
u
l
e
33

A
d
j
.
To
t
a
l

B
i
l
l
i
n
g
EX
H
I
B
I
T

N
O
.

CA
S
E

N
O
.

I
P
C
-
94
-
M.

B
R
I
L
l
.

I
P
C
O
PA
G
E

6

O
F

2
0
Du
s
k

t
o
Xd
a
h
o

p
o
w
e
r

c
o
m
p
a
n
y
IP
C
-
E
-
9
4
-
5
pr
o
p
o
s
e
d

R
a
t
e
s
st
a
t
e

o
f

I
d
a
h
o
19
9
3

N
o
r
m
a
l
i
z
e
d

D
a
t
a
Da
w
n

c
u
s
t
o
m
e
r

L
i
g
h
t
i
n
g

-

S
c
h
e
d
u
l
e

1
5
(1
)
(2
)
(3
)
(4
)
(5
)
(6
)
(7
)
Li
n
e
cu
r
r
e
n
t
cu
r
r
e
n
t
pr
o
p
o
s
e
d
pr
o
p
o
s
e
d
.J
i
!
L
De
s
c
r
i
ti
o
n
Us
e
La
m
p
s
Ra
t
e
Fa
c
i
l
i
t
i
e
s
Re
v
e
n
u
e
Ra
t
e
Re
v
e
n
u
e
Re
s
i
d
e
n
t
i
a
l
10
0

W
a
t
t

S
o
d
i
u
m

V
a
p
o
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Idaho Power company
IPC-E-94-5
Proposed Rates
Typical Monthly Billing Comparison
state of Idaho
Traffic Control Signal Lighting - Schedule 42
1.0
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MU . a.. U u...0-:9:0zON'"t-Z-la5wQ:wIV)IXI(j.c( '.c(wU~CL
(1)(2)(3)(4)
Line Current Proposed Difference Percent
Lamp Type (1\Difference
12 or Less Hours:60 Watt $0.$0.$ ( 0 . 04 )( 5 . 63) \
100 Watt 1.18 1.12 (0.06)( 5 . 08 ) \
150 Watt 1. 77 1.68 (0.09)( 5 . 08 ) \
200 Watt ( 0 . 12)(5.11)\
250 Watt (0.15)(5.10)\
13 to 18 Hours:60 Watt 1.06 1.01 (0.05)(4.72)\
100 Watt 1. 77 1.68 (0.09)( 5 . 08)
150 Watt (0.13)(4.91)\
200 Watt (0.18)(S.10)\
250 Watt (0.22)(4.99)\
19 to 24 Hours:60 Watt 1.41 1.34 ( O. 07)(4.96)\
100 Watt (0.12)(5.11)\
150 Watt (0.18)(S.10)\
200 Watt (0.24)(S.10)\
250 Watt (0.29)(4.92) \
Current Proposed Revenue Percent
Description Revenue Revenue Difference Difference
Bills 488
kWh 761,462
Total Revenue 194,599 184,885 (9,714)( .. . 99 ) \
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Billing Comparisons and Rate Design
Impacts of Proposed Rates
Idaho Power Company
IPC-E-94-5
Typical Monthly Billing Comparison
State of Idaho
Residential Service - Schedule 1
(1)(2)(3)(4)(5)(6)
Average Percent
Line Energy Current Proposed Difference Percent No.of Total
( kWh)(1)Difference Bi 11 in Billin
$7.$2.$ ( 5 . 00)(66.67)\369 98\
100 27\366 21\
200 12. 54 33.40\367 62\
300 14. 10 17.24.54\034 72\
400 18.22.20.04\12,334 08\
500 23.27.17.44\15,233 27\
600 28.32.15.67\16,801 92\
700 32.37.14.40\17,166 07\
800 37.42.13.45\16,783 91\
900 42.47.12.72\15,760 49\
1, 000 47 . 02 52.12.10\14,450 95\
100 51.57.11. 62\12,916 32\
200 56.62.11. 22\11,433 71\
1, 500 70.77 . 82 10.35\26,324 10.84\
2 , 000 94.102.45\25,266 10.40\
2, 500 117.128.10.92\13,649 62\
3, 000 141.153.12.56\639 56\
4 , 000 188.203.15.13\315 84\
5 , 000 235.253.18.7 .86\647 1. 50\
LI)
~UO'"a..U-a..LL.ZO-:O"""Z~-a5 w 0;:: w:EV)CX)C).c:( . c:(wU~c...
Idaho Power company
IPC-E-94-5
Typical Monthly Billing Comparison
State of Idaho
Samll General Service - Schedule 7
(1)(2)(3)(4)(5)(6)
Average Percent
Line Energy Current Proposed Difference Percent No.of Total
( kWh)Rate (1)Difference Billin Billin
$7.$2.$(4.75)(63.33)\950 90\
100 1.26 16.80\232 21.46\
200 10.14.4. 3B 42.12\414 90\
300 15.20.33.27\771 26\
400 20.26.28.89\442 91\
500 26.32 . 82 26.23\201 93\
600 31. 20 38.24.49\071 39\
700 36.44.23.21\952 90\
800 41.50.22.28\865 55\
900 46.56.10.21. 56\774 3. 17\
1 , 000 51. 99 62.10.20.98\725 97\
500 77.92.14.19.21\776 11.39\
000 103.123.19.18.32\787 33\
2, 500 129.153.23.17.79\119 59\
3 , 000 155.183.27.17.44\633 2 . 60\
4 , 000 207.243.35.17.00\432 77\
5 , 000 259.303.43.16.74\122 o. 50\
10,000 519.604.84.16.21\115 47\
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IDAHO PO-VEl-. CO\1PA'\"1
SCHEDULE 24 TR"-'\2\H 55 I 0', ~.rR':ICE CCSTO\1ERS
PROPOSED BILLI:\\' l\1J'ACT
...... .
MU -~ULL.a-:~azaNY')~z-,mwQ2w
:r:v)cc ~c( .C(wU~~
PAGE
ANNUAL
ACCQtJl\"T CURRENT PROPOSED PERCENT LOAD
NUMBER BILL BILL DIFFERENCE OIANGE AcroR
---------------------------------------------
06520047698 37,971.40,757.785.3139
20560202428 53,467.56,992.524.3317
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Service Schedules for Proposed Rates
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 1-
SCHEDULE WG-.l
RESIDENTIAL SERVICE
AVAILABILITY
Service under this schedule is cvcilcble cAt points on the Company s interconnected system
within t~e Stcte of Idc,",o :re existing facilities of adequ~te capacity and desired phase and voltage
are adjacent to the pEremlses to be served. and additional Investment by the Company for new
transmission. substation or terminal facilities is not necessary to supply the desired service.
APPLICABILITY
Service under this schedule is cpDliccble t:J:o eElectric sService required for Residential Service I
Customers for general domestic uses. including single phase motors of 7'h horsepower rating or less
subject to the following conditions:
(1) \Nhen existing seNise is s~pplie~ thrGl;Jgh aRe meter to ~ar~ than GRe ResiElenti~ ~~::c::
g:~g
:~r. ~~ ~~~~~ far Sl;JC~ service will ~e campvfed by mvltJpl',:lng th~ """mber Gf Cl::Isto~er
k' . n eoc~ blask by the maximum number af Damestls ~er/lse CustomeFE. ~ervlce
under t~is paragraph (1) is Rat available ta ReW GvstameFE.
(21) When a portion of a dwelling is used regularly for business. professional or other gainful
purposes. the pfremises will be classified as non-residential and the appropriate schedules
applied. However. if the wiring is so arranged that the service for residential purposes can
metered separately. this S~chedule will be applied to such service.
l2l Whenever ibe..Customer's equipment does not conform to !bi:..Company s specifications. I
service will be supplied under the appropriate General Service Schedule.
j3).This schedule is Neot applicable to standbyservice. service for resale. or shared service.
TYPE OF SERVICE
The Nee of service erovided under this schedulcService is single phose. alternating current at
approximately 120 or 240 volts and f6OJ- cycles. supplied through one meter at one pfoint of
ElDelivery. Upon request by the owner of multi-family dwellings. the Company may provide 120/208 volt
service for multi-family dwellings when all equipment is U L approved to operate at 120/208 volts.
WATER HEATING
Electric storage water heating equipment shall conform to specifications of the Underwriters
Laboratories. Inc.. and the Company and its installation shall conform to all National. State and
Municipal Codes and may be equipped with one or two heating units. No single heating unit shall
exceed 6 kW: and where two heating units are used in a single tank. these units shall be so interlocked
that not more than 6 kW can be connected at anyone time.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 1 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 1-
SCHEDULE NG-.l
RESIDENTIAL SERVICE
(Continued)
RESIDENTIAL SPACE HEATING
All space heating equipment to be served by 1be..Company s ~System shall be single phase
equipment approved by Underwriters' Laboratories. Inc.. and the equipment and its installation sholl
conform to 011 Nationol, State end Municipol Codes end to the following:
Individual resistance-type units for space heating larger then 1.650 watts sholl be
designed to operate at 240 or 208 volts. end no single unit shall be larger then t6t kW. ,
Heating units of two kW or larger sholl be controlled by approved thermostatic devices. When 0
group of heating units. with 0 total capacity of more than t6t kW. is to be actuated by a
single thermostat. the controlling switch shall be so designed that not more than ~ f6t kW can
be switched on or off at ~one time. Supplemental resistance-type heaters. that may be used
with a heat exchanger. sholl comply with the specifications listed above for such units.
MONTHLY CHARGE
Customer Chorge
S2 50 Cler month
Enercv Charae
Base Rate
.5.O2.ll 7916ct
Power Cost
Adiustment*
1449ct
Effective
Rate
.5 1 MO 4 8165ct per kWh for all kWh
Minimum Charae
The monthlv Minimum Chor sholl be the sum of the Customer Chor e ond the Energy
ChorQe.$7.59 \:IAle$$ a hiiher miRim\:lm is required IJnaer aireement for a IiAe eK.feRsion.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
post due "fteeR f1~ days from the date on which rendered sr as extended 9'1 Oepesit and Ter:mination.
Rule 20
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 2 OF 49
IDAHO POWER COMP ANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 7-
SCHEDULE NG-.7
SMAll GENERAL SERVICE
AVAILABilITY
Sl:r/lce "oper !hl' ~cheduJe i~ oyoijoble Agt points on the Compony's Interconnected system \
within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage
are adjacent to the pfremises to be served.
APPLICABILITY
;:.;.: ~~
~~r t~~ ,cherlul= 10 npcllccble ;10 eElec1ric sService suppl1ed to 0 Customer. where
seFViQe i t e C~stemer is s~J'iJ'iliee ~neer tRis SQRee~le. at one Point of Delivery and
measured through one meter. This ~~hedule is applicable to Customers with energy loads that ee not
exceeeQm 000 kilewett he'o:lFS fkWhh er less.per month for or more months during the Annual
Review Period. This Schedule is also applicable to non-profit or tax supported ball fields. fairgrounds or
rodeo grounds with high ElDemands and intermittent use exceeding 3.000 kWh per month. Ibis
schedule is Neot applicable to ~tondby service service fer resale. SX,.shared service...QLiQ individual or
multiple family dwellings first served through one meter after February 9. 1982.
TYPE OF SERVICE
The tvee 0\ I~il:" prpviged ~n"'er 'his Iches:!ule b Soingle and/or three-phose. at approximately
...... j6Of cycles and at Ihe slandard service vaRage available al the I'fremises la be served.
ANNIVERSARY DATE
The Annive~my Dote is the dote en which service is initially taken under this schedule.
ANNUAL REVIEW PERIOD
~::'2 :;;;W P~riad i. Ih~ 12-
t!'o~jh "!!rind ~n~ing :.yflh It;.e ~nnng Period ", wbi"h Ihe
~~~~; ~
~~v;:~;:.:~~I~E~:~~~p ~'" ~t thp ~~p ?f the 6nnu~1 R~iew PeriQd. t:"ch ,-",tern!,,' s
~=T
:~~: '::~
:::;;; I.n - ,erv'ce el'o.hlioty un~er Ih': ~~~I
: ~"
1'Ae
""
;;~~~~~d ""
~~~
tRis SEihee~le .... ill Be reviewed a~nually far farefaer rate
56ReQ~le assignment. C""stSFReFS thet qualify for service unQer a different schedule will be transferred to
the appropriate FeMrschedule effective with the next Billing Period. The accounts of new Customers or
Customers whose load characteristics are experiencing fundamental changes may be reviewed morefrequently.
EXHIBIT NO.
CASE NO. 'PC-94-
M. BRill. 'PCO
PAGE 3 Of 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 7-
SCHEDULE WG-.7
SMALL GENERAL SERVICE
!~ontinued)
MONTHLY CHARGE
Customer Cherge
~2 75 oer month
Enerav Cherae
Bose Rate
Power Cost
Adiustment8
1449Q:
Effective
Rate
6..1.S25 3 4 4J~per kWh for all kWh
Minimum Charae
The monthly Minimum Charge shell he the sum of the Customer Charge end the eEnergy
&Charge. for the menth. but not less than Seven and SOIlQO DellaFS 1$7.SQ).
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
post due fifteen 15)- days from the dote on which rendered.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill, IPca
PAGE 4 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET NO. 9-
SCHEDULE NQ-.9
LARGE GENERAL SERVICE
AVAILABILITY
Service under this schedule is ovoiloble Agt points on the Company s interconnected system I
within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage
are adjacent to the pfremises to be served.
APPLICABILITY
Service under this schedule is opplicoble +10 firm eElectric sService supplied to a Customer
where service required by the Customer is supplied under this schedule at one Point of Delivery gnd
measured through one meter.
This service is applicable to Customers whose energy usage exceeds 3.000 kilewott hours fkW~
per month for 0 minimum of three or mor-e months during the Annual Review Period and whose Gaming
eQemand Gees Rot exceedi~ less then kilowl:3tts (kW~ three times for ten or more months during
the Annual Review Period.
This schedule is not applicable to standby service service for resale, QLshared service, gL1Q I
individual or multiple family dwellings first served through one meter after February 9, 1982.
TYPE OF SERVICE
The tvpe of service provided under this schedule $~ingle and/or three-phase, at approximately
f6(ij cycles and at the standard service voltage available at the pfremises to be served.
ANNIVERSARY QATE
The Anniver5ory Qote is the dote on which service is initiolly token under this schedule.
ANNUAL REVIEW PERIOD
e :~~~~ ':~i
~: :~=~~
is the 12-month oeriod endin9 with th: BillinQ. Period in which the
~u5tom .' s
..
- r5 Eoch yeor ot the end of the Annuol Review Penod eoch ~~s
:~: :~f:~:=~:~
.:::=~
~ervi~e eliQ",~!iy u~"':' fh;, ~~hedl'~ CydoD""" The eie"
",.
~ €I 6 C S 'his ScReal:lle will se FeVleWeG 1:3""1:11:311-,. far praper rote scRedule
as5ignment. C~demeFE tnot ~qualify for service under a different schedule wUl be transferred to the
appropriate ~schedule effective with the next Billing Period. The accounts of new Customers ar
Customers whose load characteristics are experiencing fundamental changes may be reviewed more
frequently.
BASIC lOAQ CAPAC':ITY
~~
~c.:~~~~~ ~".::~~~ :e
~ gv,:,o~e cI !he b/fo ore"te~1 MrJ-7"'" mo ~1!'1v ~m;~Q Oer:cnnds
estoblis 1 - riod which Includes end ends with the current Blillno Penod.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ, IPCO
PAGE 5 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 9-
SCHEDULE NG-.9
LARGE GENERAL SERVICE
(Continued)
BilliNG DEMAND
!be Billing Demand is +lhe overage kW supplied during the 15-consecutive-minute period of
maximum use .during the ~:~cr
~;;~;g
ailJiDg.,pfe~od adjusted for Power Factor. W~eR i~e Cv~t~~er'~
=.;:;;:; :: :: ~:
es BCtS_,ACS 9'(
~~":.':~~::::.:::: ::: ::::~. '~~
;::~~:e; te aeteFmiRe the DemaRa by mvlti~lying the FRea~ured kW by
85 arIa aivieing lay t~e aGiual Pewer Feder.
FACILITIES BEYONDTHF POINT OF DEl1VFRY
...
~:;;;;'~:;:\ ~: ;~~;';,~d =n
~~~:'rs pnd ot~r fl"""Di insto!lE'd t:evpnd the ~i:;o.,:
Deliver)! b l t I d by thE! Comoany In consideratIon of the Customer
paying a Facilities Charge to the Comoanv.
;o.,;,,~~:~~:~~,:~:i
~~~"~~~~:..
~ P~Dt of D..fiv..ry will p.. ~..t fprth i? C Di~~u~on fociliti~
:'~I
~':
=:::'T'n: ~~
~.
. the Compony . IQYe.t!)1enl'Q Fopllh~. B:d ~
~~\%, o~~e
~~~~;~~~~'
;j;i'
~:::,
fh~ c~;tomer
" '~.
~;~e reQu;reme!'" the ~o",
::.~:;~
r deletions of facIlities by forwarding to the Customer a
revised Distribution Facilities Investment Reoort.
~~:~ :~e;~~:~ C
~~~;:.
r ;e
~~~~~.~::
Comoanv to remove or rE!install or change Comoanv-
~ F~~~tl
=~ ~~ ~
I ~ the Customer shall Day to the comoan
~ ..~~~:'~"::: ~:. ~~~~~'~~:~ :~~~~;~
~ ,,~n
;p
Non-sQ!yabb;. ~q,t as us"d ~e"'in
~~~~:~
~ ~ n
~~~~ ';:," ~:;: '' .
. d vert,eap, af jI1e faClllt,es Ie" the d1ff_~ ~en
te . :';;~~;d :;~d r;~~';~llabor cost including appropriate ovE!rhead costs.
POWER FACTOR
~ ~ ~:-
s E
:;;'"
Fad"" is Ie.. !haD AS P"iCeDi g!\ delen'T\ined bx mea~~relJ1ent
~~~ ~c
~~~~ ~~;~~;::~ ~; ~~~~~
;;;;;y pdiust Ill': ~~ D)"gsur..~ to d~t"m1i~: t BDnngIv n 5 oercent and dlvldlno bv the actual Power Factor
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRIll, IPCO
PAGE 6 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 9-
SCHEDULE
LARGE GENERAL SERVICE
(Continued)
MONTHLY CHARGE
Be5ic C'.herge
!oO 311 oer kW of Be..ic toed C'.epedtv
!')pmpnd Fn~rov onD FociRtlp, ,-horoe.
The ~onthlv C'.heroe i5 the sum of the ~u5tomer Be5ic
et the following chsr~es cempvteei st the fslls"ling rotes:
~FC:ONDARY SERVICE
C'.udomer C'.herge
$5 50 oer month
Demond Choroe
$~
per kW for 011 kW of Demond
Enerav Choroe
Bose Rote
Power Cost
Adiustmenf8
O.1449ct
Effective
Rcite
per kWh for 011 kWh
fedlitie5 Cherge
Mini
~~~~
The t .mum C'.herQe 5hell be the ..um of the C'.U5tomer C'.:~r
~~~~~
~ic C:heroe the
Demond CherQe end the Energv Chorgesa fer tAS MSRtA. 9,.,t Ret Ie" than $15-.00.
Thi5 Power Co..t Ac:Uudment (Schedule 55\ end thi5 Effective Rete exoire Mev 15 1995.
PRIMARY SERVICE
Cudomer'Cherce
$85 00 oer month
pe5ic CherQe
!oO 711 oer kW of Be5ic toed C:epediy
Demend Cherce
$3 04 oer kW for ell kW of Demend
EXHIBIT NO.
CASE NO. IPC-94-
M. BRILZ. IPca
PAGE 7 Of 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 9-
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
PRIMARY SERVICE (Continued)
~~:i~~;C~~Q
~ '
invE;!stmE;!nt in Comoanv-ownE;!d Facilities Beyond the Point of Delivery timE;!s 1 .
pE;!rcE;!nt.
fnerQY Charge Effective
Rate
2 2939ct
Power Cost
~~~;~;ent*~~~~~~te oer kWh for all kWh
~~i
~~~~~
i.,;~;;,ci'c~
~'
n:m~m rha,oe ,hall b~ th~ sum af the ,,""pme, ('.hmoe Ihe Basil' Charge the
------ _
harge thE;! EnerQv Charl;Je and the FacilitiE;!s ChargE;!.
This Power Cost AqjustmE;!nt (Schedule 55) and this EffE;!ctivE;! RatE;! expire May 15 1995.
TRANSMISSION SERVICE
~ustomer Charge
$8500 per month
&asic Charge
SO 39 oer kW of Basic load Capacitv
Demand CharQe
S? 95 per kW for all kW of Demand
fnergy Charge Effective
Rate
?2A60ct
Power Cost~~~;~;en"~~~~ ~~te oE;!r kWh for all kWh
~~g
I investment in Company-ownE;!d Facilities BE;!yond the Point of Deliverv times 1.
percent.
~~i ~~?n~mum Cherne shall be the sum of the Customer Charne the Basic Charne the
C;~~~d'Ch~~~ .
..
w ---
---.- ---~- --------- --
thE;! EnerqV CharQe and the Facilities Charc~e.
This Power Cost Adjustment (Schedule 55) and this Effective Rote expire May 15. 1995.
pAYMENT
The monthly bm rendered for service supplied hereunder is payable upon receipt. and becomes
post due fifteen ~15t days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 8 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF NO.
ORIGINAL SHEET NO. 15-
SCHEDULE NQ-.15
DUSK TO DAWN CUSTOMER LIGHTING
AVAILABILITY
~ervice under this schedule is available +10 commercial institutions. industrial plants. and
residential Customers presently served from the Company s interconnected system within the State of
Idaho.where existing overhead secondary distribution facilities of adequate capacity. phose and
voltage are presently available adjacent to the pfremises to be lighted. &1Jbject ta the Campsny
three year QanveF&ien praSifsFA ta hiSih pres&1Jre Seai1JM ..'spar ar FRetsl "aliae f:ixt1Jres
:it
~~~~~~A~ U~~1i ~~ ~~H.CUl~ ~~I OR ~mR ~IOV'~~ER 1. 1
~~"
a:
PReSSY
. . p .. .
lID~ 1..P S~R.ICe. ~IO ~I~.. ~..ERCLJRY ...peR 1..~FZ
~~RVICE Will iE P.VP.lV.ile ,II,S Of ~IOV~MiER 1. 1990.
APPLICABILITY
Service under this schedule is ooplicoble +10 eflectric sService provided for the outdoor dusk to
dawn lighting of commercial. industrial and domestic Customer grounds. yards. driveways and
pfremises by means of a Company-owned luminary. mounted on cn..existing Company pole with a I
support bracket. automatically controlled by a photoelectric relay.
CHARACTER OF SERVICE
The facilities required for supplying service. including fixture. lamp. control relay. and support
bracket for mounting on an existing Company pole with secondary service. are supplied. installed.
owned and maintained by the Company in accordance with the Company s standards and
specifications. All necessary repairs and maintenance work. including lamp renewal. will be performed
by the Company only during the regularly scheduled working hours of the Company. and the
Company shall be allowed 72 hours. subsequent to notification by the Customer. for replacing any
burned out lamps. Lamps are energized each night from one-half hour after sunset until one-half hour
before sunrise. thereby providing approximately ~hours of pfremises lighting~er year.
NEW FACILITIES
Where facilities of the Company are not presently available for a lamp installation which will
provide satisfactory lighting service for the Customer's pfremises. the Company may extend its I
overhead secondary service facilities. including secondary conductor. poles. anchors. etc.. a distance
not to exceed 300 feet to supply the desired service. all in accordance with the charges specified
below.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 9 OF 49
IDAHO POWER COMP ANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 15-
SCHEDULE NG-.1 5
DUSK TO DAWN CUSTOMER LIGHTING
(Continued)
MONTHLY CHARGES
Monthly per unit charge on existing facilities:
AREA LIGHTING
High Pressure Average Bose Power Cost Effective
odium Va lumens Rate ustment-Rate
100 watt 5SO $0.
200 watt 19.800 $0.
400 watt 45.000 $li.5Z~$0.$li.ZZ~
Mcrcurv VaDer tole tolew Service
17a wa#47~$0.$ 9
400 V/a#19.110 $1 a $0.$15
1000 \'\'a#~aO $2i $25
FLOOD LIGHTING
Hiah Pressure Sodium VaDor
200 watt 19.800 $0.10
400 watt 45.000 $0.20
Metal Halide
400 watt 28.800 $0.$lB.ZD3+:83
1000 watt 88.000 $O.
Moraur:\' "~seer ~Ie ~leVl ~erviGe
400 watt 19.110 $0.$19
000 wa#~8.iaO $28 ~0.$28
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
The Monthly Charge for New Facilities to be installed. such as overhead (or equivalent)
secondary conductor. poles. anchors. etc.. shall be 1.75 percent of the estimated
installed cost thereof.
The Company may provide underground service from existing secondary facilities when
1be-Customer pays the estimated nonsalvable cost of underground facilities.
PAYMENT
The monthly bill for service supplied hereunder is payable upon receipt. and becomes post due
fifteen fl5j. days from the dote on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 10 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 19-
SCHEDULE NG-.19
LARGE POWER SERVICE
A V AILABIUTY
Service under this schedule is available at points on the Company s interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service. those facilities
provided for under Schevdle 71 Rul~ will be provided under the terms and conditions of that
schedule
w=. To the extent that additional facilities not provided for under Scheelule 71 Rul~ H.including
transmission and/or substation facilities. are required to provide the requested service. special
arrangements will be made in a separate agreement between the Customer and the Company.
Each Customer is required to enter into a Uniform Large Power Service Agreement prior to being
served under this schedule.
APPLICABILITY
Service under this schedule is applicable to Customers with firm electric demand of +&QLQOQ to
25.000 kilewatts fkWt at a single Point of Delivery who have entered into a Uniform Large Power Service
Agreement. If the aggregate power requirement of a Customer who receives service at one or more
Points of Delivery on the same pfremises exceeds 25.000 kW. the Customer is ineligible for service under I
this schedule and is required to make special contract arrangements with the Company.
This schedule is not applicable to service for resale. m..shared scFViQe QL,.irrigation service. tg
~tondby or supol~m~ntol s~rvic~. unl~ss th~ Custom~r has ~nt~r~d into 0 Uniform Standby S~rvice
AQr~~m~nt with th~ Comoony.or !s;Lmulti-family dwellings.
SERVICE ELIGIBILITY
To be eligible for initial service under this schedule. a Customer must register a metered demand
of 7SOl.OOQ kW or more under one of the Company s other ~schedules for at least three Billing I
Periods during the Customer's Annual Review Period. A Customer who meets this metered demand
criterion can be transferred to this schedule effective with the Billing Period immediately following
eligibility provided the Customer enters into a Uniform Lorge Power Service Agreement with the
Company.
The rates and charges provided for in this sche~ule will be billed beginning with the first Billing
Period during which service is provided under this schedule.
Continued Eliaibilitv. To be eligible for continued service under this schedule. a Customer's
metered demand at a single Point of Delivery must equal or exceed 7SO.1..CCD. kW for at least three Billing
Periods during the Customer's Annual Review Period.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 11 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 19-
SCHEDULE NG-.19
LARGE POWER SERVICE
(Continued)
TYPE OF SERVICE
The Type of Service provided under this schedule is single and/or three-phase at approximately
60 cycles and at the primary ~tandard servic~voltage available at the ~fremises to be served. but not
leu thsR 12.kilovolts
POI~J:T Of DELIVERY
The Point of Delivery is the point '....here the Compan,,s lines fiFSt become asjecent ts the
C""domer's property.
ANNIVERSARY DATE
The Anniversary Dote is the dote on which initial service is taken under this schedule.
For each Customer ~receiviAg~ service under this schedule prior to January 1. 1993. the
Anniversary Date will Be iLthe Customer's c""R'ent review dote set forth in the Company s records and
used os of January 1. 1993. for the Annual Review Period.
ANNUAL REVIEW PERIOD
The Annual Review Period is the twelve12-month period ending with the Billing Period in which
the Customer's Anniversary Dote falls. Each year. at the end of the Annual Review Period. each
Customer's account will be reviewed for continued service eligibility under this schedule. Customers
who do not meet the Service Eligibility provisions will be transferred to the appropriate Fete-schedule I
effective with the next Billing Period and the Uniform Large Power Service Agreement will be canceled.
Customers who can document that they will no longer be eligible for continued service under
this schedule as a result of installing conservation measures. may, upon application to and approval by
the Comcanv Vice President of Distribution. be transferred to a different FEHe-schedule prior to the end I
of the Annual Review Period and the Uniform Large Power Service Agreement will be canceled.
BASIC LOAD CAPACITY
The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than~~kW.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill, IPCO
P A(";F 1? nF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF NO. 101 ORIGINAL SHEET NO. 19-
SCHEDULE NQ-.19
LARGE POWER SERVICE
(Continued)
BILLING DEMAND
The Billing Demond is the overage kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period. adjusted for Power Foetor. but not less than +SQl..QOQ kW.
FACILITIES BEYOND THE POINT OF DELIVERY
At the option of the Company. transformers and other facilities beyond the Point of Delivery
may be owned. operated. and maintained by the Company in consideration of the Customer paying
a Facilities Charge to the Company.
Company-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Facilities
Investment Report provided to the Customer. As the Company s investment in Facilities Beyond the
Point of Delivery changes in order to provide the Customer's service requirements. the Company sholl
notify the Customer of the additions and/or deletions of facilities by forwarding to the Customer a
revised Distribution Facilities Investment Report.
In the event the Customer requests the Company to remove or reinstall or change Company-
owned Facilities Beyond the Point of Delivery. the Customer sholl pay to the Company the "non-
solvable cos" of such removal. reinstallation or change. Non-solvable cost as used herein is comprised
of the total or1Qincl cast~ of materials, labor and overhead~ ceds o iAtfelling the facilities. less the
difference beiween the solvable cost of material removed and removal labor cost including
appropriate overhead costs.
POWER FACTOR ADJUSTMENT
Where the Customer's Power Foetor is less than 8~ cercent.os determined by measurement I
under actual load conditions. the Company may adjust the kW measured to determine the Billing
Demond by multiplying the measured kW by 85 percent and dividing by the actual Power Foetor.
TEMPORARY SUSPENSION
When a Customer has property invoked General Rule f23. Temoorarv Susoension of Demond
. ,
the Basic load Capacity and Billing Demond sholl be prorated based on the period of such suspension
in accordance with General Rule f23. In the event the Customer's metered demand is less than
+SQLOOa kW during the period of such suspension. the Basic load Capacity and Billing Demond will
set equal to +50.1.DCQ kW for purposes of determining the Customer's monthly Minimum Charge.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPca
PAGE 13 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 19-
SCHEDULE NG-.19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the
Customer Basic. Demond. Energy. end Facilities Charges
at the following rates:
Customer Cherge
i5 50 oer month
SFC:ONDARY SERVICE
Basic Charae
$Q.3AG.7+ per kW of Basic load Capacity
Demond Charae
$~
per kW for all kW of Billing Demond
Enerav Charae
Bose Rate
Power Cost
Adiustmen"
14491t
Effective
Rate
2 63622.191 &It per kWh for ell kWh
Fedlities Chcrge
Minimum Charae
The monthly Minimum Charge sholl be the sum of the Customer Cherl~e the Basic Charge. the
Demond Charge. gmLthe Energy Charge. ORa tRe Feeilities Charge 'J:Re CemaRd Cnarge
we\:/ta ge rea\:/Qed 9'1 a High Vettese Credit if applisable.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PRIMARY SERVICE
Demend Cherge
$3 04 oer kW for ell kW of Billing Demend
~ustomer Choroe
SB5 00 c~r month
~esic CherQe
SO 76 oer kW of Besic toed Capedtv
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 14 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 19-
SCHEDUl E 19
I ARGE POWER SERVICE
iContinued)
MONTHLY CHARGE (Continued)
~~~:;~te
Power CO!it
AdjU!itment
0 1449ct
Effective
Rate
'21916ct oer kWh for all kWh
Energy Charge
Facilitie!i Charae
OAe and seven tenths percent (1.7'1(.) times t!he Company s investment in Compony-owned
Facilities Beyond the Point of Delivery time!i 1 7 oercent.
,",iah Vettesc Credit (WRen service is taken at 44 kV ar obave)
$0.59 f'ler k\\' af 011 kW af Billing gernand
~:ir
:~~t~~~~n~mum Charge !ihall be the !ium of the Cu!itomer Charge the Ba!iic Charge the
Demond Charge th~ Energy Chan~e and the Facilitie!i Charge.
) .
Thi!i Power Cmt Adju!itment (Schedule 55) and thi!i Effective Rate exoire May 15 1995.
~~~ ~~te
~:~:~
. invedment in Comoanv-ownp-d Facilitie!i Beyond the Point of Deliverv times 1 7
percent.
Power CO!it
~diudmenf8
1449ct
Effective
Rate
'2 1460ct oer kWh for all kWh
TRANSMISSION SERVICE
~ustomer Charge
~85 00 per month
~asic Charge
$0 39 oer kW of Basic Load CapacitY
Demond Charge
~2 95 oer kW for all kW of Billina Demand
EnerQV CharQe
~~i
~~~:
t .mum CharQe !ihall be the sum of the Customer Charee. the Basic Charge the
p;~and Charge the Enerov Charge and the Facilities Chorce.
This Power Cmt Acfju!itment (Schedule 551 and this Effective Rate expire May 15 1995.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 15 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 19-
SCHEDLJL F 19
~ARGE POWER SERVICE
(Continued)
PAYMENT
The monthly bi1\ for service supplied hereunder is poyable upon receipt. and becomes post due
15 days from the date on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRIll. IPCO
PAGE 16 OF 49
IDAHO POWER COMPANY
I.P.. N . 26 TARIFF NO. ORIGINAL SHEET NO. 19-
SCHEDULE NG-.19
LARGE POWER SERVICE
IDAHO POWER COMPANY
Uniform large Power Service Agreement
DISTRICT ACCOUNT NO
THIS AGREEMENT Mode this day of
between
whose bOGng address is
hereinafter coiled Customer. and IDAHO POWER COMPANY.
A corporation with its principal office located at 1221 West Idaho Street. Boise. Idoho. hereinafter called Company:
NOW THEREfORE. Th. partl.. agr.. OJ follows:1. ~Company sholl agree to supply voU. ~inole- or three-phose eElectric sService up to the amount of kilowatts per month lor !ba..Customer's
faciGties located at or near County of
State of Idoho. in the of Section Township Range2. The avoilabffity of power in excess of the amount stated in Paragraph 1 above is not guaranteed and its taking by the
Customer may result in a complete or partial curtailment of service to the Customer. The Company has the right to instaD. at the
Customer's expense. any device necessary to protect the Company s system from damage which may be caused by the taking of
power in excess of that stated in Paragraph 1. The Customer sholl be responsible for any damages to the Company's system or
damages to third parties resulting from the Customer s taking of power in excess of that stated in Paragraph 1.
The terms of this Agreement shall not become binding upon the parties untO signed by both parties.
..
The initial dote of deRvery of power and energy under this Agreement is subject to the Company s abi&ty to obtain
required labor. materials. equipment. and/or satisfactory rights-of-way and to comply with goverrvnental regulations.5. The term of this Agreement shoD be for one year from and cfler the Initial Service Date thereof. and shall cutamaticcDv
renew and extend each yeer thereafter. This Agreement can be canceled 1) by either party provided written notice of termination is
given to the other not tess than tweIo.oe12 months prior to the desired tennination dote. or 2) as provided for in the Company's I
Schedule 19 or its successor schedules.6. This Agreement and the rates. terms and conditions of service set forth or incorporated herein. and the respective rights
and obfigations of the parties hereunder. shell be subject to vaRd lews and to the regulatory authority and orders. rules end
regulations of the Idaho PubRc Utilities Convrission and such other administrative bodies having juriscfiction.7. Nothing herein sholl be construed os imiting the Idaho Pubic Utilities Commission from changing any terms. rates.
charges. classification or service. or any rules. regulation or conditions relating to service under this Agreement. or construed os
affecting the right of the Company or the Customer to unilateroDy make oppication to the Commission for any such change.
8. the Company's Schedule 19. any revisions to thot schedule. and/or any successor schedule is to be considered os pert
of this Agreement.9. In any action at law or eQUity conmenced under this Agreement and upon which judgment is rendered. the prev0l1ng
party. as pert of such judgment. shaH be entitled to recover on costs. including reasonable ottomeys fees. incurred on account of such
action.
10.ThIs Agreement replaces a1d supersedes the Agreement between the parties dated the day of
Dote
(APPROPRIATE SIGNATURES)
Initiol Service Dote
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill, IPCO
PAGE 17 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 24-
SCHEDULE WG-.24
IRRIGATION SERVICE
AVAILABILITY
Service under this schedule is available Act points on the Company s interconnected system
within the State of Idaho for loads up to 25.000 kilewQtts where existing facilities of adequate
capacity and desired phose and voltage are adjacent to the pfremises to be served. and additional
investment by the Company for new transmission. substation or terminal facilities is not necessary to
supply the desired service. If the aggregate power requirement of a Customer who receives service at
one or more Points of Delivery on the some pfremises exceeds 25.000 kW. special contract I
arrangements will be required.
Service under this schedule is not available to Blackfoot District Customers during the term of the
Blackfoot District Irrigation Service Pilot Program. Schedule 24-Pilot. and Blackfoot District Customers
desiring irrigation service are required to toke service under Schedule 24-Pilot. Blackfoot District
Customers have account numbers which include "72" in positions three and four (e.g.. 0072-000000-0).
The Blackfoot District Irrigation Service Pilot Program is effective beginning September 1. 1994 and
terminating October 1. 1996 with the exception that THE "LATE PAYMENT" AND "SEASONAL ADVANCE"
PROVISIONS OF SCHEDULE 24-PllOT Will BE APPLIED TO ANY BLACKFOOT DISTRICT IRRIGATION
CUSTOMER'S MONTHLY BILLS RENDERED UNDER SCHEDULE 24 DURING 1994 PRIOR TO SEPTEMBER 1. 1994.
APPLICABILITY
Service under this schedule is applicable +10 power and energy supplied to form customers and
organizations at one Point of Delivery and through one meter for the operation of irrigation pump
motors. The Company will connect service and disconnect service once each calendar year without
charge during normal business hours. For all other customer requested connections or disconnections
the Customer will pay the actual expense incurred whether or not the additional connect or disconneCt
is performed during normal business hours.
SEASONAL DEFINITION
The Irrigation Season will begin with the Customer's meter reading for the May Billing Period and
end with the Customer's meter reading for the September Billing Period. The beginning cycles of a
Billing Period may actually be based on meter readings token not more than Zsea.'eA days prior to the I
start of the corresponding calendar month.
TYPE OF SERVICE
The tYee of service provided under this schedule Ssingle and/or three-phose. altemating
current. at approximately 60 cycles and at the standard voltage available at the pfremises to be
served.
~~:I~ay se ",sterea eR the law teAsieR siaa ef C\lste",er's wansfSFmSFS. iF! which event
meBS\lfe"'ent v!iII se eSj\lsteEi fer wansfeFmer leues.
EXHIBIT NO. 38
CASE NO.IPC-94-
M. 8Rlll. IPCO
PAGE 18 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101
BASIC': I CAD CAPACITY
INAL HEET N . 24-
SCHEDULE NG-. 24
IRRIGATION SERVICE
(Continued)
~~~~e~~ ~opacitv i~ the avercge ef the twe Qreate~t nen-zerc monthly metered demands
i~~~:~~~
~~; ~=:
~-;d ~;;gi;;n1no ~1th tb~ tjnvpmber ~1mno Perin'" no~ pnp1ng w1tb theII I n Basic ChorQ I~ oDphed te the Boslc lead COpOCltv.
~ B ~~~:Ocitv i~ calculated each menth when the menthly bill i~ DreDored For the
~~ ~~~
~RP~;:
~::"~ ~~~:~~-
:f5 ~:~.
:d ~,,~inni~a ~ith !he Nav~mber Billing p~6o~. Ih" BPSic
~~~~" ~' ~~"
t.u
;:':.
~~~~;:L
:' '
~~~n~.
;;' ,,; d ~"P~cl1Y for ~och ,uti'""",,",. bIll ""DO" !he '
.'-=~~. ~'
~ Bu
: ~
the difference between the BasIc I cod Ca~)Oclty
~:~~~~::i::~;:~: ~~b~E~
~=~~
~nd the ~IJ" I oed rppo~jjy og,;iolt whi"b ~': ~o~c
=~~= =':;-:= "
xpmpl~ 111~s!rpl"s Ib~ comoulollpn of g~d blllp'!;! fori o s i~; t~~ fi~t biil t; the 12-menth Deried is orepored fer the March Billina
Peried.
~~~~h
Metered
Demond
~~~~h
:~~
~~ust
100 kW
~ ~g ~~~:
; 25 kW
Annual Ameunt
BilLING DEMAND
Basic load
Capacity
Basic lead Capacity
Billed the Basic Charge
100 kW
125 kW
150 kW
150 kW
150 kW
150 kW
150 kW
50 kW pOO kW 50%)
75kW 1125 kW 50 kWI
25 kW 1150 kW 125 JeW)
0 JeW 1150 kW 150 kW'
0 JeW 1150 kW 150 JeW,
0 kW 1150 kW 150 kW'
150 kW
The Billino Demand +the overage kW suppfied during the 15-consecutive-minute period of
maximum use during the meter reasini BilllcQ..~feriod"pdjusted fer Pewer Foctor.PROVIDED That at ibJa
Company s option the Billing eDemand of a single motor installation of 5 horsepower and less may be
:::e~ :~~c ~u::~:f kilowatts equal to the number of horsepower but not less than one kW. When
=~ ~=::"'7.: f=~i':: ~:~ "8'88"IIS881"1/. B5 cj ~18""i".cj By me"'
~~~!..;':~".':
~ a s. n . . Galust tt:le kW ta aeteFR=lIAe t~e Oe~aAs b'l ~ultJplYlng tho
measures kW BY 85 ana aiviaini BY t~e aGtual Pawer faotar. etered power demands in kUowatts
which exceed 13~ percent of the total connected horsepower served through one
Point of
DeliveryseF\"iee eannectian will not be used for billing purposes unless and until verified by field test in
the presence of the Customer to be the result of normal pumping operations. If a demand in excess of
1~ percent of the connected horsepower is the result of abnormal conditions existing on the
Company s interconnected system or the Customer's system. including occidental equipment failure or
electrical supply interruption which results in 1be..temporary separation of the Company~ and ibJa
Customer's system. the eBilling eQemand sholl be 1~ percent of the connected horsepower. The
Customer may appeal the Company s billing decision to the Idaho Public Utilities Commission in cases
of dispute.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 19 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 24-
SCHEDULE NG-. 24
IRRIGATION SERVICE
(Continued)
FACIlITIES BEYOND THF POINT OF DELIVERY
:~he ~p~~: ~f the Comparw trcnsformers end other fecilities beyend the Point of Delivery
mey b ted end meinteined by the Comoenv in considerction of the Customer Devino
e Fecilities Charge to the Compeny.
Compeny-owned Fecilities Bevond the Point of Delivery will be set forth in e Distribution Fecilities
~;~:t
';~: ~~:~ :~~~~~
:~ the custo,:,",er. As the Compeny s invest":,ent in Fecilities Bevond the
~~ _
I h der to orovlde the Customer's service reeutrements the Company shell
if;, ~~; C~:t~;~; cl'h~ edditions end/or deletions of fecilities bv forwardino to the Customer e
revised Distribution Fecilities Investment Reoort.
In the event the Customer requests the Comoeny to remove or reinstell or change Company-
~;~:~
F~~~~~:~ ~~~~~~h: Poi~t of D:livery the Customer shell pey to the Como ~y the "~on-
. -
s h I: relnstelletlon or chenge. Non-selveble cost es used herein IS compnsed
~;~: :~~I~~~~~ ~~~s ~f meteriels lebor end overheeds of !he fe~ilities less t~e difference betweenIe t f erial removed end removellebor cost Including eppropnete overhead costs.
POWER FACTOR ADJUSTMENT
Where the Customer's Power Fedor is less then 85 percent es determined by measurement
~'::~ ~~~~~~~~
~~~diti~ns the Comoeny may edjust th~ ~~ measured te determine the Billing
y no the meesured kW by 85 oercent end divIding bv the aduel Power Fedor.
MONTHLY CHARGE
The MonthlY Charoes is the sum of the ~ustomer Basic Demend. Enerov. end Fecilities
Charoescharges cemputed at the following rates:
SECONDARY SERVICE
Basic CharQe
15 45 oer kW of Basic Loed Cepecitv oer year
Customer Charge
$1000 per month
Demond Charee
per kW of BilliDg"Demand
No Demand Charge
. Irrigation Season
Out of Season
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill, IPCO
PAGE 20 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 24-
SCHEDULE WQ-. 24
IRRIGATION SERVICE
(Continued)
MONTHLY CHARGE (Continued)
Enerav Charae
Power Cost
Adiustmenr
1449~
1449~
Effective
Rate
per kWh Irrigatibn Season
per kWh Out of Season
Base Rote
2.B32Z &8 ~ li~
3. ~ 172ft
Minimum Chofae
The mont~v Mi':,imum ChofQe sholl be the sum of the Customer ChmQe the Bosie Chorge. the
Demond ChofQe ond the EnefQV Chmge.$lli.OO per EiaRReetea month
This Power Cost Adjustment ISchedule 55) ond this Effective Rote expire May 15. 1995.
~t;~:It~~~ C
~~-
C - ;;:,..
~;
antracts far 100 k':\' or mare and takes service at 000 'lolts or higher andom aviaes na transfor:mstian e~l:Jipment. the fallawiRg sreait will spply ta those
8i11iRg Months wRen kW af OemEms is meterea sAd billed.
$S9.00 for tRe fir:st 100 kW af Oemsna. plus
li9 per kW far all gasitionsl kW af Oem and
TRANSMISSION SFRVICE
Cudomer Chorge
185 00 oer month
Bo!Jic Chofge
11 72 oer kW of Bosie lood Copodtv oer yeor
Demond Chmge
1295 per kW of Billing Demond
No Demond ChofQe
Irriootion Semol)
Out of Seoson
EnerQV Chmoe
~~~~:~te
; ~;S3;
Power Co!Jt
Adiudmenr
0 1449ct
0 1449ct
Effective
Rote
'2 8437ct
3 5BO2ct
oer kWh IrriQotion Seo!Jon
oer kWh Out of Seoson
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 21 OF 49
IDAHO POWER COMPANY
I.P.. N 26.TARIFF N . 1 ORIGINAL SHEET NO. 24-
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
MONTHLY CHARGE (Continued)
~~~~g
' investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent
~:i:~~t~~~~~mum Charge shall be the sum of the Customer Charge the Basic Charge the
Demand CharQe the Energv Charge and the Facilities Charge.
This Power Cost Adjustment /Schedule 55) and this Effective Rate ex Dire May 15 1995.
PAYMENT
All monthly billings for eElectric sService supplied hereunder are payable upon receipt. and
become past due 15 days from the date on which rendered.
1. Monthlv Cash Advances: A monthly cash advance equal to the current ~ate times I
the peak monthly use based on previous usage history for that account and for that Customer
will be required from:
An advance payment for irrigation Caustomers is required under the following conditions:
a. Customers that did not pay all of their monthly billings on or before the past due
date. but paid their final bill on or before the past due date for the previous season.
b. Customers who were required to pay a seasonal advance for the previous
season. THI~ PROVISIO~II~ ~Io:r EFFEc:rIVE UHm. THE 1991IRRICATIO~1 SEASO~I.
The monthly cash advance will be applied to the Customer's final bill for that season.
2. Seasonal Advances: Customers that did not pay their final bill on or before the past due
date for the previous season will be required to pay a seasonal cash advance. or provide a
guarantee of payment from an acceptable bank or financial institution located in the
Company s service territory. The seasonal cash advance will be applied to the Customer's
account upon receipt and the Customer's monthly billings will be deducted from the seasonal
advance as they occur. The seasonal advance for a specific installation will be computed as
follows:
The charge for the electrical usage at current rates for the specific installation.. less the
amount of the tax refund.. based on the previous year's data. . The advance may be
modified due to a change in crops.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPce
PAGE 22 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 24-
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
PAYMENTS IC:ontinuedH
3. New Customer.A seasonal advance may be required for a new account at the
Company s discretion. The seasonal advance will be computed using the following formula:
a. Monthly ~Demand (billing kW) will be determined by multiplying 80 percent
times the connected horsepower.b. Monthly Energy (billing kWh) will be determined by multiplying 80 percent times
720 hours times the Monthly BillinQ Demand.
c. The Billing Demand and the Energy values ore multiplied by the current rates to I
determine the estimated monthly bill.d. The estimated monthly bill will be multiplied by the number of months appropriate
for the Customer's crop (up to a maximum of 4 months).
4. 8ankructcv or Receivershic: An adequate assurance of payment os agreed to by the
utility or as may be ordered by a court of competent jurisdiction or the IPUC, sholl be required
from any Ceustomer for whom on order for relief has been entered under the federal I
bankruptcy lows, or for whom a receiver has been appointed in a court proceeding. The
maximum amount required for each season sholl not exceed a payment equal to a seasonal
advance. For each irrigation season, on adequate assurance of payment sholl be required as
agreed to by the utility, or as may be ordered by a court of competent jurisdiction, or the IPUC.
This requirement sholl continue from the date of the order for relief in bankruptcy, or the court'
order appointing a receiver, until the debtor's discharge in bankruptcy or the dismissal of the
court proceeding. A Ceustomer who has been discharged from bankruptcy or whose I
receivership proceeding hos been terminated will be required to pay on advance at the start of
the following season to the extent required by the payment provisions listed under the other
Paymenr' sections of Schedule Ne-. 24.
INTEREST PAYMENTS
Interest will be credited by the Company on irrigation advances required under this schedule at
the annual percentage rate of 8 percent. Interest will be computed at a periodic doily rate (annual
percentage rate divided by 365 days) and will not accrue prior to March 15 or after November 15 of
each year. All irrigation advances held by the Company will be refunded with interest on or before
November 15 and moiled to the Customer's last known address within 10 days.
MonthlY Advance For those Customers who have mode a monthly advance, interest
will be credited to the Customer's account when the advance payment is applied
against the Customer's final bill for the season.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill, IPca
PAGE 23 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 24-
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
INTEREST PAYMENTS (Continued)
Seasonal Advance For those Customers who have made a seasonal cash advance.
interest will accrue monthly on only that part of the seasonal advance which remains
after deductions.
Each irrigation Customer. upon making a seasonal or monthly advance payment. wul be required to
furnish to the Company an IRS Tax 10 or Social Security number for the Company s IRS reporting requirements.
If a Customer tenders to the Company an irrigation odvance which has not been requested or
demanded by the Company. the Company may refuse to accept and retain such advance. If. however.
the Company accepts or retains the advance. the Company wul not pay interest on the irrigation advance.
LATE PAYMENT CHARGE
A Late Payment Charge wRl be assessed Schedule 24 Customers as provided under
Schedule
CeReral R\:Ile 30 or C eReral R\:Ile 31. whicRever is applicable.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 24 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL . 24P-
SCHEDULE NG-.24-PILOT
IRRIGATION SERVICE
AVAILABILITY
This schedule is available to Ceustomers in the Blackfoot District in place of the Company
Schedule 24. Service under Schedule 24 is not available to Blackfoot District Ceustomers during the
term of the Pilot Program. Blackfoot District Customers have account numbers which include 7Z'
positions three and four le.goo 0072-00000o-o). SERVICE UNDER THIS SCHEDULE IS EFFECTIVE BEGINNING
SEPTEMBER 1. 1994 AND TERMINATING OCTOBER 1. 1996. On October 1. 1996 all customers served under
this schedule will be transferred to the appropriate Fete-schedule.
Service under this schedule is available at points on the Company s interconnected system for
loads up to 25.000 kilewot1s where existing facilities of adequate capacity and desired phase and
voltage are adjacent to the pfremises to be served. and additional investment by the Company for
new transmission. substation or terminal facilities is not necessary to supply the desired service. If the
aggregate power requirement of a Customer who receives service at one or more Points of Delivery on
the same pfremises exceeds 25.000 kW. special contract arrangements will be required.
APPLICABILITY
This schedule is applicable to power and energy supplied to form Ceustomers and organizations
at one Point of Delivery and through one meter for the operation of irrigation pump motors.
TYPE OF SERVICE
The ivpe of !iervice orovided under this !ichedule i!i S~ingle and/or three-phase. altemating
current. at approximately 60 cycles and at the standard voltage available at the pf,remises to
served.
SERVICE CONNECTION
Upon connection or reconnection for service the Customer will be required to pay a $30
aAccount pfrocessing eCharge. For any customer requested service connection or reconnection
performed outside of normal business hours. the Customer will be required to pay an after hours charge
of $30 in addition to the $30 Aeccount ft;H"ocessing Ceharge. Service will remain connected
throughout the calendar year with the following exceptions:
Customer Reauest.At the Customer's request. the Company will disconnect service
during normal business hours at the end of the Customer's pumping operation at no
charge to the eCustomer. Customers who request service be disconnected are required
to pay the $30 aAccount pf,rocessing eCharge upon reconnection for service.
Late Payments. The Company will disconnect service to Customers who have two or
more late payments during a twelve12 month period. A payment will be considered late
if the balance owing for electric service totals $50 or more and is not paid on or before
the past due date. Service disconnections due to late payments will not be made during
the Irrigation Season. Customer's whose service is disconnected due to late payments
are required to pay the $30 aAccount pfrocessing &Charge upon reconnection for I
service.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 25 OF 49
IDAHO POWER COMPANY
LP.. N . 26 TARIFF N . 1 ORIGINAL SHEET NO. 24P-
SCHEDULE ~ 24-PILOT
IRRIGATION SERVICE
(Continued)
SERVICE CONNECTION (Continued)
3. Customer Maintenance. At the Customer's request. the Company will disconnect and
reconnect service in order for the Customer to perform maintenance. The Customer will be required to
pay the actual time and mileage expense incurred by the Company to disconnect and reconnect
service. The $30 a6ccount pfrocessing GCharge will not apply when service is reconnected
subsequent to a disconnection for maintenance. The Minimum Ch0f90 or Customer Charge, as~will continue to apply to Customers whose service is disconnected for customer
maintenance.
SEASONAL DEFINITION
The lnigation Season will begin with the Customer's meter reading for the May Billing Period and
end with the Customer's meter reading for the September Billing Period. The beginning cycles of a
Billing Period may actually be based on meter readings taken not more than ~Z days prior to the
start of the corresponding calendar month.
M~ING
Service mQY be metered on the law tensisA side of Customer's trOASformcFS. in AiGh eve
mec:Jsurement will be Qd ndsFR=ler losses.
BASIC LOAD CAPACITY
The Basic load Caoec:itv is the averaae of the two Qreatest non-zero monthlY metered demands
~~t~~:~~~g~~fi
t~~ 12-;;'~~th ~eriod beQinnina ~ith th~ November Billina Period an~ endina with theII B,ihna Penod. The Basic Charae IS aoohed to the BasIc load Caoaclty.
The Basic loed Caoacitv is calculated each month when the monthly bill is orecared. For the
~~ ~~~ ~;
;oa~:~ ~~ri~i ~:~ 12-month oeriod beQinninQ with the November Billing Period. the Basic
. e. ~~ ao .: d .- c~nt of the Besic load Cacac:itv For each subseeuent bill durina the 12-
~:~:u ~~
ri~~ :h
~ ~e~i~: Charae
is aoolied to the difference between the Basic load Caoac:itv
t o ~urrent bill is oreoared and the Basic load Ceoecitv aaainst which the Basic
;~~~~~:~~~i~: ~f~~
~~Ii:d The follo~ina examcle iIIustrat~s th~ comoutetion of and billin
? .
for
5 Imino the first bill for the 12-month cenod IS oreoared for the Merch Btlhna
Period:
Bilnna Metered
Month Demand
~~~;h
~~~:
M;;
~ ~g
~~~e
~~~:
~~~ust
Annual Amount
Basic load
Caoac:itv
Besic load Caoac:itv
Billed the Basic CharQe
100 kW
125 kW
150 kW
15OIc:W
15OIc:W
150 kW
150 kW
50 kW 11 00 kW . 50%1
75 kW 1125 kW - 50 kW1
25 kW 1150 kW - 125 kW1
0 kW 1150 kW -150 kW1
0 kW 1150 kW - 150 Ic:WI
0 kW 1150 Ic:W - 150 Ic:WI
150 kW
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 26 Of 49
IDAHO POWER COMP ANY
I.P.. N . 26 TARIFF N . 101 ORIGINAL SHEET NO. 24P-
SCHEDULE ~ 24-PILOT
IRRIGATION SERVICE
(Continued)
Bit LING DEMAND
The Billing Demand is +the average kW supplied during the 15-consecutive-minute period of
maximum use during the meter reeaing 6illlc.,u~feriod aqjJJsted for Power Factor.PROVIDED Thet at !be
Company s option the BillinQ eDemand of a single motor installation of 5 horsepower and less may be
~ :~~~e ~~r;::r of kilowetts equal to the number of horsepower but not less than one kW. When
.. er yactor IS less than 8& percent la95w~g. as aetem~\lnea by measurement under
~;;tuel~~ ~~~ditians. the Compeny ma',' aejust the k'N to eetermine the Demand by multiplying the
measured k',\' 9'1 8& and aiviefing 9'1 the act\o'al Power ractoF.Metered power demands in kilowatts
which exceed 13~ percent of the total connected horsepower served through one service
connection will not be used for billing purposes unless and until verified by field test in the presence of
the Customer to be the result of normal pumping operations. If a demand in excess of 13~ percent of I
the connected horsepower is the result of abnormal conditions existing on the Company
interconnected system or the Customer's system. including occidental equipment failure or electrical
supply interruption which results in ~temporary separation of the Company~ and !be..Customer's
system. the eB,illing eCemand shall be 13~~ercent of the connected horsepower. The Customer may
appeal the Company s billing decision to the Idaho Public Utilities Commission in cases of dispute.
FACILITIES BEYOND THE POINT OF DELIVERY
::ne ~p
=~:~:
the Company transformers and other facilities beyond the Point of Delivery
Q'\ay b e r d. and maintained by the C:ompanv in consideration of the Customer paying
a Facilities CharQe to the Company.
~ompany-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Facilitie:i
~;.
~~t
:,;=~:
E~::
:~~~~
:~ :r
~ custor:ner As the Comcany s invest~ent in Facilities Beyond the
~~~ ~ _
I h ta movlde the Customer's service reqUIrements the ComDany shall
i tt,; C::St~;~; ;th~ additions and/or deletions of facilities bv forwardinQ to the Customer a
revised Distribution Facilities Investment Reppr1.
In the event the Lustomer reauests the Comcanv to remove or reinstall or change C:omcany-
~:~ F~~:~:~ ~~~~~d :v
~ ~~~
~~ D:liverv the Customer shall cay to the Comp the "~on-
~LJ
;:
. s ch. m 01 st lotion or chanQe Non-salvable cost as used herein IS compnsed
~~~' ~~ ~~~:~
:~~n~ ~~t~ ~~~~~rials labor and overheads of ~he fa~ilities less t~e difference betweente oved and removal labor cost Indudlna approcnate overhead costs.
POWER FACTOR ADJUSTMENT
the Customer's Power Factor is less than 85 cercent. as determined bv measurement
~~~ :~~~~~
~~~:-;;E: ~~
c~;;;-~onv rncv o(ji~" 'h~ ~\;' megsureo;j to (jet".."I"" It'" RnliOO
. Iv'a ~~ed kW bv 85 percent and dlvldlna by the actual Power Factor.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 27 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 24P-
SCHEDULE NG-. 24-PILOT
IRRIGATION SERVICE
(Continued)
MONTHLY CHARGE
The Monthlv Charge i!; the sum of the Cu!;tomer Bmic Demand EnerQv and Facilitie!;
Charge!;cnarges csR1p~ted at the following rates:
SECONDARY SERVICE
Customer Charge
$ 1 0 00 oer month
Ba!;ic Charge
$5 45 oer kW of Bmic toad Capacity oer year
Demand Charae
$~
per kW of ~Demand
No Demond Charge
Irrigation Season
Out of Season
Enerav Charae
Power Cost
Adiustmenr
1449tt
1449tt
Effective
Rate
298462.8294tt per kWh Irrigation Season
3 7596~.S'21tt per kWh Out of Season
Base Rate
2 83972.'8~Stt
3 61473.4172tt
Minimum ~har
The mont v M.nimum Charge shOll be the !;um of the Cu!;tomer Charge the Bmic Charge the
Demand Charge and the EnerQV Charge.$l 99 per ssnnected manth
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
~:~~:It~~~ ~i
t~~-C - ;;;;..
;~ :.
anirect" far 1 00 k'A' .ar mere. gAg feke" "eNise. at H.OO? v~lts ar higner. endam . lete" Aa trandaFFf\ahaA e~\:Ilpment. tne fallewlng sredlt will epp\.tl ta those
8i11ing MaAtN when kJN af gemend is metered enet billed.
$S9.00 fer tne fiBt 100 kW af gamene. plVE
S" per k't.' far all eetElitianal kW af gemand
TRANSMISSION SERVICE
Customer Charge
Jo85 00 oer month
Basic Charge
Jol 72 oer kW of BLC oer vear
I:)emand Charge
~~95 ~er kW of Demand
Demond Charge
Irrioation Season
out of Sea!;on
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 28 OF 49
IDAHO POWER COMPANY
t.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 24P-
SCHEDULE 24-PILOT
IRRIGATION SERVICE
(Continued
MONTHLY CHARGE (Continued)
EnerQv ChCJrge
~~~:~te
; :;~;:
Power Cost
~~u:~:,ent
0: 1 ~~9;
Effective
RCJte
2 8437ct
3 5802ct
oer kWh ImQCJtiCJn SeCJson
oer kWh Out of Semon
~~i~~~~QI investment in ComoCJny-owned FCJcilities Beyond the Point CJf Delivery times 1.1
percent.
~~i
~~~~~~,,:,~~~
~a . :mum Charge ~hgll be the ,urn at j~.~ Cusjpmer C:hprc;J1' thl' Rp,IC ,.harc;J~ the
rQe the Energy C':hmQe CJnd the FCJclhtles Chmge.
(a,This Power Cost Adjustment (Schedule 55) CJnd this Effective RCJte exoire MCJY 15. 1995.
PAYMENT
All monthly billings for electric service supplied hereunder are payable upon receipt. and
become post due 15 days from the dote on which rendered. THE "LATE PAYMENT' AND "SEASONAL
ADVANCE" PROVISIONS OF THIS PILOT PROGRAM WILL BE APPLIED TO ANY MONTHLY BILLS RENDERED
UNDER SCHEDULE 24 DURING 1994 PRIOR TO SEPTEMBER 1, 1994.
Seasonal Advance. A seasonal advance payment for irrigation Csustomers is required under
the following conditions:
1. Existina Customers: Customers who have two or more late payments during a
melve12 ,
month period wnl be required to pay a seasonal cash advance. or provide a guarantee of payment
from an acceptable bank or financial institution located in the Company s service territory. A payment
will be considered iate if the balance owing for fetectric Sservice totals $50 or more and is not paid on
or before the past due date. The seasonal cash advance will be applied to the Custome(s account
upon receipt and the Custome(s monthly billings will be deducted from the seasonal advance as they.
occur. The seasonal advance for a specific installation will be computed as follows:
The charge for the electrical usage at current rates for the specific installation less the amount of
the tax refund based on the previous yea(s data. The advance may be modified due to a
change in crops.
New Customer.A seasonal advance may be required for a new account at the Company's
discretion. The seasonal advance will be computed using the following formula:
Monthly BillinQ Deman (eilliFli kWJ wnl be determined by multiplying 80 percent
times the connected horsepower.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRILZ. IPCO
PAGE 29 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 24P-
SCHEDULE 24-PILOT
IRRIGATION SERVICE
(Continued)
PAYMENT~ IContinued)l
Monthly Energy (billing kWh) will be determined by multiplying 80 percent times 720
hours times the Monthly Billing Demand.
The Billing Demand and the Energy values are multiplied by the current retes to I
determine the estimated monthly bill.
The estimated monthly bill will be multiplied by the number of months appropria!e for
the Customer's crop (up to a maximum of 4 months).
BankruDtcv or ReceivershiD. An adequate assurance of payment as agreed to by the utility or as
may be ordered by a court of competent jurisdiction or the IPUC. shall be required from any CGustomer I
for whom an order for relief has been entered under the federal bankruptcy laws. or for whom a
receiver has been appointed in a court proceeding. The maximum amount required for each season
shall not exceed a payment equal to a seasonal advance. For each irrigation season. an adequate
assurance of payment shall be required as agreed to by the utility. or as may be ordered by a court of
competent jurisdiction. or the IPUC. This requirement shall continue from the date of the order for relief
in bankruptcy. or the court's order appointing a receiver. until the debtor's discharge in bankruptcy or
the dismissal of the court proceeding. A Ceustomer who has been discharged from bankruptcy or
whose receivership proceeding has been terminated will be required to pay an advance at the start of
the following season to the extent required by the payment provisions listed under the other "Peymenf'
sections of Schedule We-.24-PILOT.
INTEREST PAYMENTS
Interest will be credited by the Company on irrigation advances required under this schedule
the annual percentage rate of 8 percent. Interest will be computed at a periodic daily rate (annual
percentage rate divided by 365 days) and will not accrue prior to March 15 or after November 15 of
each year. All irrigation advances held by the Company will be refunded with interest on or before
November 15 and mailed to the Customer's last known address within 10 days.
Monthlv Advance:For those Customers who have made a monthly advance. interest
will be credited to the Customer's account when the advance payment is applied
against the Customer's final bill for the season.
Seasonal Advance:For those Customers who have made a seasonal cash advance.
interest will accrue monthly on only that part of the seasonal advance which remains
after deductions.
Each irrigation Customer. upon making a seasonal or monthly advance payment. wnt be required
furnish to the Company an IRS Tax ID or Social Security number for the Company's IRS reporting requirements.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRIll. IPca
PAGE 30 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 24P-
SCHEDULE 24-PllOT
IRRIGATION SERVICE
(Continued)
INTEREST PAYMENTS (Continued)
If a Customer tenders to the Company an inigation advance which has not been requested or
demanded by the Company. the Company may refuse to accept and retain such advance. If. however.
the Company accepts or retains the advance. the Company will not pay interest on the inigation advance.
LATE PAYMENT CHARGE
A Late Payment Charge wDl be assessed Schedule 24-..E1L.QI Customers as provided under Schedule
6,6.Cenefal Rule 30 er C eAeral Rule 31. 'IJRiQRever is apjafieable.
EXHIBIT NO.
CASE NO. IPC-94-5
M. BRILZ. IPCO
PAGE 31 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 40-
SCHEDULE NO-. 40
UN METERED GENERAL SERVICE
AVAILABILITY
Service under this schedule is available Agt points on the Company s interconnected system
within the State af Idaho where existing secondary distribution facilities of adequate capacity. phase
and voltage are available adjacent to the Customer~ pfremises and the only investment required by
the Company is an overhead service drop.
APPLICABILITY
Service under +lhis S~chedule applies to eElectric sService for 1be...Customer:J single- or multiple-
unit loads up to 1.500 watts per unit where the size of the load and period of operation are fixed and. as
a result. actual usage can be accurately determined. Service may include. but is not limited to. street
and highway lighting. security lighting. telephone booths and CATV power supplies which serve line
amplifiers. Facilities to supply service under this S~chedule shall be installed so that service cannot be
extended to ~Customer:.s loads served under other schedules. Service under this schedtJle is ~Dot
applicable to shored or temporary service. or to 1rnLCustomer~ loods on pf,remises which have
metered service.
SPECIAL TERMS AND CONDITIONS
Ihe..Customer shall pay for all Company investment. except 1be...overhead service drop. required
to provide service requested by ~Customer. Iba-Customer is responsible for installing. owning and
maintaining all equipment. including necessary underground circuitry and related facilities to connect
with 1biLCompany s facilities at 1biLCompany designated Points of Delivery. If 1bLCustomer's I
equipment is not property maintained. service to the specific equipment will be terminated.
lighting se~/ea \Inger tRis Sshes\:Ile m\lst be cenwalled by g pheta electric;; devise af the "hail off'
~pe.Energy used by CATV power supplies which serve line amplifiers will be determined by the power
supply manufacturer's nameplate input rating assuming continuous operation.
SP~CI.A..l TERMS A~ID CO~IDt:TIO~IS (Centin\lea)
Ib.e..Company is only responsible for supplying energy to the Point of Delivery and. at its expense.
may check energy consumption at any time.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 32 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 40-
SCHEDULE NQ-. 40
UNMETERED GENERAL SERVICE
(Continued)
MONTHLY CHARGE 81lL1r.IG
The average monthly kilewaf.t ~euFS of energy usage shall be estimated by the Company.
based on tt1e..Customer's electric equipment and on~twelfth (1/12)of the annual hours of operation
thereof. Since the service provided is unmetered. failure of kCustomer's equipment will not be reason
for a reduction in the MffiOnthly C".horoe9illiAg. The rate for all kile'NGf.t heuFS of energy sholl be:
Base Rate
Power Cost
Adiustment
151t
Effective
Rate
s.:z:z.
Minimum Chorae
$1.50 per month& per unit
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due fifteen fl5t days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 33 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 41-
SCHEDULE NG-. 41
MUNICIPAL STREET LIGHTING
SERVICE
AVAILABILITY
S~rvice under this sch~dule is available ~lhroughout the Company s service area within the State
of Idaho where street lighting wires and fixtures can be installed on !bi;LCompany s existing distributionfacilities.
APPLICABILITY
S~rvic~ und~r this sch~dul~ is apolicabl~+10 service required by municipalities for the lighting of
public streets. alleys. public grounds. and thoroughfares. Street lighting lamps will be energized each
night from dusk until dawn.
SERVICE LOCATION AND PERIOD
Street lighting facility locations. type of unit and lamp sizes. as changed from time to time
written request of 1be..Customer and agreed to by 1be..Company. sholl be as shown on an Exhibit A for
each Customer receiving service under this S~chedule. The in-service date for each street lighting
facility will be maintained on Exhibit A.
The minimum service period for any street lightir:'g facility is .teA fl~ years. IWLCompany. upon
written notification from ~Customer. will remove a street lighting facility:
1. At no cost to 1be.-Customer. if such facility has been in service for no less than the
minimum service period;
Upon payment to tbe..Company of the removal cost. if such facility has been in service
for less than the minimum service period.
AU - OVERHEAD LIGHTING - COMPANY-OWNED SYSTEM
The facilities required for supplying service. including7 faxture. lamp. control relay. mast arm or
mounting on an existing utility pole. and energy for the operation thereof. are supplied. installed. owned
and maintained by the Company. All necessary repairs. maintenance work. including group lamp
replacement and glassware cleaning. will be performed by the Company during the regularly
scheduled working hours of the Company on 1be.-Company~ schedule. Individual lamps will be
replaced on bum out os soon as reasonably possible after notification by tbe..Customer and subject to
1bf:..Company s operating schedules and requirements.
MONTHLY CHARGE PER LAMP
High Pressure
Sodium VaDor
100 Watt
200 Watt
400 Watt
Average
lumens
5SO
19.800
45.000
Base
Rate
$ .6.3n7.OO
$ l.3Z&+$l
Power Cost
Adiustment-
$0.
$0.
$0.
Effective
Rate
UiY+
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 34 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 41-
SCHEDULE-NG-. 41
MUNICIPAL STREET LIGHTING
SERVICE
(Continued)
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5. 1964 required to be used for street
lighting only:
Woodpole........................ $~perpole
Steel pole. . . .
. . .. . . . . . . . . . . . . . . . ..
$6...ZJ7.A8 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost difference
between overhead and underground. or the Customer agrees to pay a monthly charge of 1.
perceat of the estimated cost difference.
B" - CUSTOMER-QWNED SYSTEM
The Customer's lighting system. including posts or standards. fixtures. initial installation of lamps
and underground cables with suitable terminals for connection to tmLCompany s distribution system. is I
installed and owned by the Customer.
Service supplied by the Company includes operation of the system. energy. lamp renewals.
cleaning of glassware. and replacement of defective ballasts and photocells which are standgr,d to the I
Company-owned street light units. Service does not include the lobar or material cost of replacing
cables. standards. broken glassware or fIXtures. or painting or refinishing of metal poles.
NTHLY CHAR PER LAMP
High Pressure Average Bose Power Cost Effective
Sodium V lumens Rate Adiustment.Rate
100 Watt 550 $J.A23.80 $0.
200 Watt 19.800 $0.$W~
250 Watt 24.750 $0.$52B&AO
400 Watt 45.000 $Ul~$0.$aJl3g.sj1Q
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
post due fifteen ~ 1 ~ days from the date on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 35 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 41-
SCHEDULE WG-. 41
MUNICIPAL STREET LIGHTING
SERVICE
(Continued)
NO NEW SERVICE
AVAILABILITY
Service under thi~ ~chedule i~ available +lhroughout the Company s service area within th~ State
of Idaho to any Customer who. on October 31. 1981. was receiving service under this S~chedule.
APPLICABILITY
Service under thi~ ~ch~dule i~ applicable +10 service required by municipalities for the lighting of
public streets. alleys. public grounds. and thoroughfares. Street lighting lamps will be energized each
night from dusk until down.
SERVICE LOCATION AND PERIOD
Street lighting facility locations. type of unit and lamp sizes. as changed from time to time by
written request of ~Customer and agreed to by ~Company. shall be as shown on on Exhibit A for
each Customer receiving service under this S~chedule. The in-service dote for each street lighting
facility will be maintained on Exhibit A.
The minimum service period for any street lighting facility is f1OJ. years. Ibe-Compony. upon
written notification from !be..Customer. will remove a street lighting facility:
At no cost to ~Customer. if such facility has been in service for no less than the
minimum service period:
Upon payment to ~Company of the removal cost. if such facility has been in service
for less than the minimum service period.
A" - OVERHEAD LIGHTING - COMPANY-OWNED SYSTEM
The facilities required for supplying service. including fixture. lamp. control relay. most arm for
mounting on an existing utility pole. and energy for the operation thereof. are supplied. installed. owned
and maintained by the Company. All necessary repairs. maintenance work. including group lamp
replacement and glassware cleaning. will be performed by the Company during the regularly
scheduled working hours of the Company on JbLCompany~ schedule. Individual lamps will be
replaced on burnout as soon os reasonably possible after notification by 1bf:..Customer and subject to
kCompany s operating schedules and requirements.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPca
PAGE 36 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 41-
SCHEDULE WG-. 41
MUNICIP Al STREET LIGHTING
SERVICE
NO NEW SERVICE
(Continued)
MONTHLY CHARGE PER LAMP
Average Base Power Cost Effective
Incandescent ~umens Rate Adiustment8 Rate
500 $0.$ 5J.8i.+4
OOO $ e $ iI
000 $0.$ z.2asm
10.000 $1Q.$0.$11.22
Mercurv Vaoor
175 Watt 654 61l2~$0.1..fJ27.;;$
2S0'1.af*1 Q. ~Qe $11.3S $0.1 ~$11.~9
400 Watt 19.125 $.1l.!Z $0.$.1.l.Zl
High Pressure
Sodium VaDor
150 Watt 14.400 $6.B2~$0.ill7-:e+
250 Watt 24.750 $0.
$~~
. (8 This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5. 1964 required to be used for street lighting
only:
Wood Pole. . . . . . .
. . . . . . . . . . . . . .
.$.l.ZQ+:8!il per pole
Steel Pole. . . . . . . . . . . . . . . . . . . . . .$6.ZJ7.48 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost difference
between overhead and underground. or the Customer agrees to pay a monthly charge of 1.
percent of the estimated cost difference.
B" - ORNAMENTAL LIGHTING - CUSTOMER-QWNED SYSTEM
The eCustomer's lighting system. including posts or standards. fJXtures. initial installation of lamps
and underground cables with suitable terminals for connection to ~Company's distribution system. is
installed and owned by the Customer.
Service supplied by the Company includes operation of the system. energy. lamp renewals.
cleaning of glossware. and replacement of defective ballasts and photocells which are standard to the
Company owned street light units. Service does not include the labor or material cost af replacing
cables. standards. broken glassware or fixtures. or painting or refinishing of metal poles.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRIU. IPca
PAGE 37 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL S ET N . 41-
SCHEDULE NG-. 41
MUNICIPAL STREET LIGHTING
SERVICE
NO NEW SERVICE
(Continued)
MONTHLY CHARGE PER LAMP
Average Base Power Cost Effective
Incandescent Lumens Rate Adiustmenr'Rate
500 $ 2.BQ3.++$0.$ 2.2Q~
000 $ 4.$0.$-4:43
000 $0.$ 5JDSM
Mercurv VaDer
175 Watt 654 $ 5J..65:+3 $0.
$~~
250 Watt 10.40&
$ &.
$0.$ e
400 Watt 19.125 $0.a.a2~
1000 Watt 47.000 $0.
High Pressure
Sodium VaDor
70 Watt 200 $ 2.22. $0.$ J.Q.33:3e
~5sem
400 Watt 21.000 $ 8.$0.$-Me
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due fifteen i1Sl days from the date on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 38 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 42-
SCHEDULE WG-. 42
TRAFFIC CONTROL SIGNAL
~IGHTING SERVICE
APPLICABILITY
SE!rvicE! undE!r this schE!dule is applicable +10 eElectric sService required for the operation of
traffic control signal lights within thE! StatE! of Idaho. Traffic control signal lamps are mounted on posts or
standards by means of brackets. most arms. or coble.
The traffic control signal fixtures. including posts or standards. brackets. mast arm. coble. lamps.
control mechanisms. fixtures. service cable. and conduit to the point of. and with suitable terminals for.
connection to the Company s underground or overhead distribution system. are installed. owned.
maintained and operated by the CustomE!rmunisipality
Service is limited to the supply of energy only for the operation of traffic control signal lights.
MONTHLY CHARGES
The monthly charge per signal fixture depends upon the number and size of lamps burning
simultaneously in each signal: also. the averoge number of hours per day the signal is operated: and
will be computed on the basis of the following monthly rate per lamp for the burning hours per 24-hour
day as specified herein: PROVIDED. HOWEVER. at the Company s option. the wattage of the signal may
be determined by test.
60 Watt
100 Watt
150 Watt
200 Watt
250 Watt
Average Daily Bose Power Cost Effective
Burnina Hours Rate Adiustmenr'Rate
12 or less $.D6Z~$0.$ .QZOO.74
13 to 18 $J..Ql +.Ge $0.$ J..Q6+.++
19 to 24 $0.UQ+:47
12 or less ill +rii $0.$UZ~
13 to 18 $0.L.W-:8'
19 to 24 $0.
12 or less $0.$L.W-:8'
13 to 18 $0.
19 to 24 $0.$J.5QU8
12 or less $0.
13 to 18 $0.$J.5QU8
19 to 24
$~~
$0.
12 or less $0.$2.223:07
13 to 18 $ill4.-4+$0.
19 to 24 $0.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due fifteen fl5J. days from the date on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 39 OF 49
IDAHO POWER COMPANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 45-
SCHEDULE NO-. 45
STANDBY SERVICE
AVAILABILITY
Standby Service under this schedule is available at points on the Company s interconnected
system within the State of Idaho where existing facilities of adequate capacity and desired phose and
voltage are available. If additional distribution facilities are required to supply the desired service. those
facilities provided for under ScheslJle 71 ~ule H will be provided under the terms and conditions of that
rule. To the extent that additional facilities not provided for under Rule..I:L including transmission and/or
substation facilities. are required to provide the requested service. special arrangements will be mode in
a separate agreement between the Customer and the Company.
Standby Service is available only to Customers taking power and energy under a Uniform Large
Power Service Agreement (Schedule 19).
APPLICABILITY
:R=Ms sService ~nder thi5 5chedule is applicable to Customers utilizing on-site generation who
request Standby Service from the Company.
These service provisions are not applicable to service for resale. to service where on-site
generation is used for only emergency supply. or to cogenerators or small power producers who have
contracted to supply power and energy.
AGREEMENT
Service shall be provided only after the Uniform Standby Service Agreement is executed by the
Customer and the Company. The term of the Agreement shall be for one year and shall automatically
renew and extend each year. unless terminated under the provisions of the Agreement. The Uniform
Standby Service Agreement wul automatically be canceled upon termination of the Schedule
Uniform large Power Service Agreement between the Customer and the Company.
TYPE OF SERVICE
The Type of Service provided under this schedule is three-phase at approximately 60 cycles and
at the primary voltage available at the pfremises to be served. but not less than 12.5 kilovolts.
DEFINITIONS
Succlementarv Contract Demond:The firm power contracted for by the Customer under the
Schedule 19 Uniform Large Power Service Agreement.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 40 OF 49
IDAHO POWER COMPANY
ORIGINAL SHEET NO. 45-LP.. N . 2 TARIFF N 101
SCHEDULE NO-. 45
STANDBY SERVICE
(Continued)
DEFINITIONS (Continued)
Succlementarv aillina Demand:The firm power supplied by the Company on a continuous basis
to supplement the Customer's own generation. Supplementary Billing Demand is equal to the
total average kW supplied during the 15-consecutive-minute period of maximum use during the
Billing Period. adjusted for Power Factor. but not less than 7-SQ.l..OOC kW nor greater than
sSupplementary Contract Demand. Supplementary Billing Demand is billed monthly under the
Demand Charge provisions of Schedule 19.
Standby Contract Demand: The self-generation backup power contracted for by the Customer
under the Uniform Standby Service Agreement.
Standby Billina Demand: The power supplied by the Company to backup the Customer's own
generation. Standby Billing Demand is equal to the total average kW supplied during the 15-
consecutive-minute period of maximum use during the Billing Period. adjusted for Power Factor.
less Supplementary Contract Demand. but not less than zero.
Total Contract Demand: The sum of the Supplementary Controct Demond and the Standby
Contract Demand.
Available Standby Cacacitv: The Total Contract Demand less the Supplementary Billing Demand
and the Standby Billing Demond. but not more than the Standby Contract Demand.
Excess Demand: The total average kW supplied during the 15-consecutive-minute period of
maximum use each day. adjusted for Power Factor. which exceeds the Total Contract Demand
by more than 5 percent.
Total Enerav ReQuirement: The total energy supplied by the Company for supplementary and
standby purposes. The Total Energy Requirement is billed monthly under the Energy Charge
provisions of Schedule 19.
POWER FACTOR ADJUSTMENT
Where the Customer's Power Foetor is less than 8~ percent.as determined by measurement I
under actual load conditions. the Company may adjust the kW measured to determine the
Supplementary Billing Demond. the Standby Billing Demond. and any Excess Demond by multiplying the
measured kW by 85 percent and dividing by the actual Power factor.
FACILITIES BEYOND THE POINT OF DELIVERY
Any Company investment in Facilities Beyond the Point of Delivery will be provided under the
terms and conditions of Schedule 19.
EXHIBIT NO. 38
CASE NO.IPC-94-
M. BRill. IPCO
PAGE 41 Of 49
IDAHO POWER COMP ANY
I.P.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 45-
SCHEDULE WO-. 45
STANDBY SERVICE
(Continued)
PARAllEL OPERATIONS
Parallel operations will only be authorized by the Company under the terms of the Uniform
Standby Service Agreement with the Customer. The Company will install a system protection package
at the Customer's expense prior to the start of parallel operations. The Customer will also pay a
Maintenance Charge of 0.7 percent per month times the investment in the protection package.
MONTHLY CHARGE
The Monthly Charge for Standby Service is the sum of the Standby Reservation Charge. the
Standby Demand Charge. and the Excess Demond Charge. if any. at the following rates:
Standby Reservation Charoe
$~
per kW of Available Standby Capacity for Customers taking Primary Service
~O 61 per kW of Available Staodby Capacity for Customers taking Transmission Service
Standby Demond Charae
$J.a2~ per kW of Standby Billing Demond for Customers takina Primary Service
~~ 70 per kW of Standby Billing Demand for Customers taking Transmission Service
Excess Demond Charae
$0.50 per kW times the sum of the doily Excess Demands recorded during the Billing Period. plus
$5.00 per kW for the highest Excess Demond recorded during the Billing Period. This charge will
not be prorated.
~iQ" Voltaoo Credit (When service is taken at ~ ~ \()/ or abave)
$0.59 per kW far all kW af Stansby 8illiAiI DaMand
MINIMUM CHARGE
The monthly Minimum Charge sholl be the sum of the Standby Reservation Charge. the Standby
Demond Charge. and the Excess Demand Charge. 1=Ae Stange', Oemand Charile wa""la ae red""c;ed
e'l a Hiil~ Valtage Credit if applisable.
CONTRIBUTION TOWARD MINIMUM CHARGES ON OTHER SCHEDULES
Any Standby Service Charges paid under this schedule sholl not be considered in determining the
Minimum Charge under any other Company schedule.
PAYMENT
The monthly bill for service supplied hereunder is payable upon receipt. and becomes past due
15 days from the dote on which rendered.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRIU. IPca
PAr..F 4? OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 4
SCHEDULE NG-. 45
STANDBY SERVICE
IDAHO POWER COMPANY
UNIFORM STANDBY SERVICE AGREEMENTDISTRICT ACCOUNT NO.
THIS AGREEMENT Mode this day
whose billing address is
hereinafter called Customer. and IDAHO POWER COMPANY. A corporation with its principal office located ot 1221 West Idaho Street
Boise. Idaho. hereinafter coDed Company:
between
NOW. THEREFORE. The parfle. agree as follows:1. The Company wiD agree to provide Standby Service to the Customer s faciDties located at or near
County of state of Idoho. in the form of three phose.
.Electric sService subject to emergency operating conditions of the Company.
van.
2. The Standby Contract Demand provided by this Agreement is kW. The Company wiD provide
electric power and energy. in backup to the Customer's on-site generation. up to the amount of the stated Standby Contract
Demond.3. The availabiDty of power in excess of the Standby Contract Demond stated in Paragraph 2 above is not
guaranteed and its taking by the Customer may result in a complete or partial curtailment of service to the Customer. The Company
hos the right to instao. at the Customer s expense. any device necessary to protect the Company s system from damage which may
be caused by the taking of power in excess of the Standby Contract Demand. The Customer wiD be responsible for any damages to
the Company s system or damages to third parties resulting from the Customer s taking of power in excess of Standby Contract
Demand.
The terms of this Agreement wm not become binding upon the parties untO signed by both parties.5. At the Company' sole discretion and after receiving written authorization from the Company. the Customer may
operate in peronei with the Company's system. Parallel operations wI be in accordance with the Company's Standards for
Interconnection and PeraUel operations and the tariff provisions for Standby Service. Any violation of these provisions wi. result in the
invneciate ciscomection of the paranel operation.6. The initial dote of service under this Agreement is subject to the Company's abffity to obtain the required labor.
materiels. equipment. and satisfactory rights-of-way. and to comply with govemmentol regulations.7. The term of this Agreement wiD be for one yeor from and otter the Initial Service Dote thereof. and will automatically
renew and extend each yeer thereafter unless written notice of termination is given by either party to the other not less than t\NeIYe12 ,
months prior to the desired termination date. This Agreement will automatically be canceled upon termination of the Customer's
Uniform Large Power Service Agreement.8. The Customer agrees to hold harmless and indemnify the Company. its officers. agents. end employees. against
loss. damage. expense end &abi6ty to third persons or injury to or death of person or injury to property proximately caused by~
Customer's construction. ownership. operation or maintenance of. or by failure of. any of the Customer's generating faci6ties.
9. This Agreement end the rates. terms and conditions of service set forth or incorporated herein. and the respective
rights and ob6gations of the parties hereunder. wiD be subject to valid lows and to the regulatory authority and orders. rules and
regulations of the Idaho Pubic Uhlities Commission and such other administrative bodies having jurisdiction.
10. Nothing herein Wll be construed os &mitlng the Idaho Pubic Uh1ities Commission from changing any rotes. charges.
dossiflcation or service. or any rules. regulation or conditions relating to service under this Agreement. or construed as affecting the
right of the Company or the Customer to unilatercly mok.e oppGcation to the Commission for any such change.
11. The Company's Schedule 45. any revisions to that schedule. and/or any successor schedule is to be considered os
port of this Agreement.
12. In any action at low or eQUity convnenced under this Agreement and upon which judgment is rendered. the
prevOl1ing party. os port of such judgment. wII be entitled to recover 01 costs. including reasonable ottomeys fees. incurred on
account of such action.
13.This Agreement replaces and supersedes the Agreement between the parties dated the day of
INITIAl SERVICE DATE
fAPPI?/,,\PI?IATF c;l("'"NATIII?F4\\Dote
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRIll. IPCO
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 101 ORIGINAL SHEET NO. 46-
SCHEDULE NG-. 46
ALTERNATE DISTRIBUTION SERVICE
AVAILABILITY
Alternate Distribution Service is available at points on the Company s interconnected system
within the State of Idaho where existing facilities. of adequate capacity and desired phose and
voltage. are adjacent to the location where Altemate Distribution Service is desired. and when
additional investment by the Company for new distribution facilities is not necessary to supply the
requested service. When additional transmission or substation facilities are required. separate
arrangements will be made between the Customer and the Company.
Alternate Distribution Service is only available to Customers taking Primarv Service under
Schedule 9 or 19.at primal)' distributisn '.'sltage levels (12.5 knavslts sr 34.5 kilavGlts).
APPlIC.A.8111TY
This schedule applies to till requests far Rew ,",Itemate Distribution Ser/ice. CustameFS receiving
Altemtite Distribution Service pRor to JtiRUtir/ 1. 1990 moy continl:le receiving service under their existing
aR'tingements until March 1. 1991. ot whicR time any customer desiRng to continue Altemate DistributiGn
Serviee will tronsfer to tRis sQRedule.
AGREEMENT
Service shall be provided only offer the Uniform Alternate Distribution Service Agreement
executed by the Customer and the Company. The term of the initial agreement shall be dependent
upon the investment required by the Company to provide the Alternate Distribution Service. but shall in
no event be less than one year. The Uniform Alternate Distnbution Service Agreement shall
automatically renew and extend each year. unless terminated under the provisions of such agreement.
TYPE OF SERVICE
Alternate Distribution Service consists of a second distribution circuit to the Customer which
bocks up the Custome(s regular distribution circuit through on automatic switching device. Alternate
Distribution Service facilities include. but are not limited to. the automatic switching device end that
portion of the distribution substation and the distribution line required to provide the service. The
kilewatts ~W~ of Alternate Distribution Service capacity sholl be specified in the Uniform Alternate
Distribution Service Agreement.
STANDARD OF SERVICEIHTeRRIJPTI81LRY
The Alternate Distnbution Service provided under this schedule is not on uninterruptible supply
and is subject to the some standard of service as iRter:ruptieilit')'provided under the Company CeRersl
Rules.J.
EXHIBIT NO. 38
CASE NO.IPC-94-
M. BRill. IPCO
PAGE 44 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 46-
SCHEDULE NO-. 46
ALTERNATE DISTRIBUTION SERVICE
(ContimJ,ed)
MONTHLY CHARGES
The Monthlv Chart;;Je is the sum of the C:apacity Charge and the Mileage Charge follewing
charges ~emplJted at the following rates:
Cacacity Charae
$~
per contracted kW of capacity. plus
Mileaae Charae
005 per kW per tenth of a mile in excess of 1.7 miles.
The distribution line will be measured to the nearest tenth of a mile from the Alternate Distribution
Service substation to the automatic switching device.
FACILITIES CHARGE
The automatic switching device will be owned. operated. and maintained by the Company in
consideration of the Customer paying to the Company Facilities Charge of 1.7 percent per month
times the Company s investment in such facilities.
CONTRIBUTION TOWARD MINIMUM CHARGE ON OTHER SCHEDULES
Any altemate Distribution Service charges paid under this schedule shall not be considered
determining the Minimum Charge under any other Company S~chedule.
PAYMENT
The monthly bill for sel"Vice supplied hereunder is ccyable upon receipt. and becomes nest due
15 dovs from the date on which rendered.
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 45 OF 49
IDAHO POWER COMPANY
LP.. N . 2 TARIFF N . 1 ORIGINAL SHEET NO. 26-
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 26
MICRON
BOISE. IDAHO
SPECIAL CONTRACT DATED MAY 1. 1994
MONTHLY CONTRACT RATE
Demond Chorae
$~
per kW of Billing Demond but not less than 25.000 kW
Contract Demond Chorae
$J...5i+.so per kW for 37.000 kW
Enerav Chorae
Bose Rate
.1.3.m
Power Cost
Adiustment*
449
Effective
Rote
mills per kWh for all energy
. (*
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 46 OF 49
IDAHO POWER COMPANY
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 2
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE NG-. 28
FOR
FMC CORPORATION
AGREEMENT FOR SUPPLY OF
INTERRUPTIBLE POWER AND ENERGY
DATED APRIL 20. 1973
MONTHLY CONTRACT RATE
(Applicable to Service Schedule A-2. A-3. and A-i)
Demand Choroes
Intenuptible Primary Contract Demand
per month per kW for the fIrSt 19:375 1cW111
$z.5Z2i.790 per month per kW for the first 11.875 kWI2I
(ii)Secondary Billing Demand
$0.00 per day per kW for the first 19:375 kWPI
$0.00 per day per kW for the first 11 :075 kWI~1
(iii)Excess Demond
per each KdleVJQt:t of Excess Demondl5l
Enerov Choroes
Primary Energy:
Bose Rote
u.zgz
Power Cost
Adiustment-
449
Effective
Rate.
mills per IcWhl6l
Secondary Energy:
23.000 mills per kWhl7l
This Power Cost Adjustment (Schedule 55) and Effective Rate expire on May 15. 1995.
CONTRACT CHANGES IN SERVICE SCHEDULES A-t. A-2. A-3. AND A-i
Section 3(a)m
(1 ) Ne-Chonge~ oer kW to 8 385 ner IcW(2) Ne-Change 15.790 oer kW to 17 579 oer IcW
Section 3(0) ffi)(3) No Change(4) No Change
Section 3(0) !iiI)(5) Ne-Chonge 187 oer kW to 10 'AS oer WI
Section 3(b)(6) Change JJUZ2~ mills per kWh to
~~
mills per kWh of primary energy
(7) No Change
EXHIBIT NO.
CASE NO. IPC-94-
M. BRIU. IPCO
PAGE 47 OF 49
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL S EET . 29-
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE
J. R. SIMPLOT COMPANY
POCATELLO. IDAHO
SPECIAL CONTRACT DATED AUGUST 27.1973
MONTHLY CONTRACT RATE
Demand Choree
$~
per kW of Billing Demondl!'
Enerev Choree
Power Cost
Adiustment'"
1.449
Effective
Rote
J 5 95613.8~7 mills per kWh for all energyl21Bose Rate
14 507
Minimum Choree
The minimum monthly charge shall be the amount computed in accordance with
Paragraph 5.1. but not less OAe I-Ivndred Thovssnd. ORe I-Ivndred Eighty Eight CallaRi
and Six~' ORe cents ~$1 00.188.61. for any month during the effective term of this
Agreement.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
Contract Chances
(1 )Contract Paroerach No 5.laL
Ne-Chonge $5 89 cer kW to $6 88 cer kW
(2)Contract Paroerach No. 5.1 rb)
Change mills to )450713.867 mills
(3)Contract Paraarach No. 5.
No Change
EXHIBIT NO. 38
CASE NO. IPC-94-
M. BRill. IPCO
D"~~ AA t"'\J:
IDAHO POWER COMPANY
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N 30-
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE NG-. 30
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE
SPECIAL CONTRACT DATED SEPTEMBER 29. 1986
CONTRACT NO. DE-AC07-86ID12588
AVAILABILITY
This schedule is available for firm retail service of electric power ond energy delivered for the
operations of the Deportment of Energy s focilities located at the Idaho Notional Engineering
Laboratory site. as provided in the Contract for Electric Service between the parties.
MONTHLY CHARGE
The monthly charge for electric service sholl be the sum of the demand and energy charges
determined at the following rates:
(a)Demond Charee
$5.C2~ per kW of Billing Demond Per Month
(b)Enerav CharaeBose Power Cost
ggm Adiustmenf8
1332311.299 449 mills per kWh for all energy
Effective
li.ZZ212.748
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
SPECIAL CONDITIONS
(1)Billina Demond:
The billing demand sholl be the overage kile'....gtts supplied during the 30-
minute period of maximum use during the month.
(2)Power Factor Adiustment:
When the power factor is less than 95 percent during the 30-minute period of
maximum load for the month. Company may adjust the measured demand to
determine the Billing Demond by multiplying the measured kW of demand by 0.95 and
dividing by the actual power factor.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 49 OF 49
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Summary of Charges and Basis for Rates
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Derivation of Standby Charges
IDAHO POWER COMPANY
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
DERIVATION OF STANDBY CHARGES
DERIVA TION OF WEIGHTED RESERVE MARGIN
Operating Weighted
Line Maximum Reserve Operating Reserve
acit Percenta Reserv Mar
Thermal Plant 991.
Hydro Plant 646.
TOTAL 638.152
DERIVA TION OF STANDBY RESER VA TION CHARGE
Generation Reserve Comoonent
Schedule 1 9 Production (Unit Cost. 5.8% WRM)
Standby Standby
Reservation Reservation
Charge Charge
Unit Co Prima Transmission
81005
Transmission Reserve Comoonent
Schedule 19 Power Supply (Unit Cost. 10% EFOR)
Schedule 19 Transmission (Unit Cost . 10% EFOR)
88456
30929
Distribution Reserve Comoonent Total Cost Bmino Units
Schedule 19 Substation 239,598 210,055
Schedule 1 9 Primary Lines 531,966 210,055
Schedule 19 Substation 261,093 210,055
Total Demand Component
TOTAL STANDBY RESERVATION CHARGE
38616
78876
08134
$4.
$1.$0.
DERIVATION OF STANDBY DEMAND CHARGE
Schedule 45 Total Demand Component
Ratio of $3.04 to $3.89676
$3.
815
Schedule 45 Primary Standby Demand Charge
Less Avoided Losses at Transmission Voltage
Schedule 45 Transmission Standby Demand Charge $3.EXHIBIT NO. 40
CASE NO. IPC-94-
M. BRill, IPCO
PAGE 1 OF 1mb.8I21184.ST ANDBY JCLS
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO. 41
M. BRILZ
Summary of Revenue Impact and
Calculation of Interim Rates
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4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILl
Billing Comparisons and Rate Design
Impacts of Interim Rates
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-94-
IDAHO POWER COMPANY
EXHIBIT NO.
M. BRILZ
Service Schedules for Interim Rates
LP.. N 26.TARIFF N . 1 ORIGINAL SHEET NO. 91-
SCHEDULE NG-.9 - INTERIM
LARGE GENERAL SERVICE
AVAilABILITY
~ervice under this schedule is available Agt points on the Company s interconnected system \
within the State of Idaho where existing facilities of adequate capacity and desired phose and voltage
are adjacent to the pfremises to be served.
APPLICABILITY
Service under this schedule is applicable ;10 firm eflectric sService supplied to a Customer
where service required by the Customer is supplied under this schedule at one Point of Delivery gnd
measured through one meter.
This service is applicable to Customers whose energy usage exceeds 3.000 kilewatt havF$tkWh~
per month for p minimum of three ar FAGre months during the Annual Review Period and whose Gailling
eQemand Gees Aet exceedis less tharl 750 kilGwatts (kW~ three times for ten or more months during the
Annual Review Period.
This schedule is not applicable to standby service service for resole. QLshared service. cr.jQ
individual or multiple family dwellings first served through one meter after February 9. 1982.
TYPE OF SERVICE
The tvoe of service orovided under this schedule Ssingle and/or three-phose. at approximately
sWy t6~ cycles and at the standard service voltage available at the pfremises to be served.
ANNIVERSARY DATE
The Anniversary Dote is the dote on which service is initially taken under this schedule.
ANNUAL REVIEW PERIOD
e ~~~~~ ~:i
~: :~:~~
~~~~e ~'2-month oerio~ endinc with th-=: Billing. Period in which the
~; 'y ~
v or at the end of the Annual Review Penod each ~~s
:~
:i;
~j=: ~=~ ~~:
~giP~ity ~nd':l'hil sChed\lI
~,
-:~~~~~ The ete..!;i"
G C 5 s Ie 'VIII tie Fevlewea anAvall'l far prapcr rate scned\lle
ElSdSAFAeAt. C\ldaFAeFE tt::lat ~qualify for service under a different schedule will be transferred to the
appropriate FCHe-schedule effective with the next Billing Period. The accounts of new Customers or
Customers whose load characteristics are experiencing fundamental changes may be reviewed more
frequently. ./
BASIC: lOAD CAPACITY
~: ~~~~~ ~P
:~;~
~e g.v:~11 01 jb" 1wo g~,,'~ Cpn-7ero m9?'hlv Bmi~g Demandsestabhs 1 - cd which Includes and ends with the current BllhnQ Penod.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRIll. IPCO
PAGE 1 OF 13
I.P.. N . 26 TARIFF NO. 101 ORIGINAL SHEET NO. 91-
SCHEDULE NQ-.9 - INTERIM
LARGE GENERAL SERVICE
(Continued)
BILLING DEMAND
The Billing Demond is +lhe overage kW supplied during the 15-consecutive-minute period of
maximum use during the meter reading mJliDg,.~feriod. ocljusted for Power Foctor When the CvEtemer'E
power faeter iE leu than 8SCJt lagging. as aeteR=Ainea kay meas\:lrement unger actu~1 ~~ :~~a
~~~~~.
C~~~;;~; ~ivd tRe kW maaE\:Irea te aateR=Aine tRe CamaRa kay multiplying tRe measurcd kW by
85 ana aividing kay the aGtual Pewer raQteF.
FACILITIES BEYOND THE POINT OF DELIVERY
DeIiVef'J ~:;bC::~~e
~. t::e ~:':'~~d ~~~~f~7:::~ b
~~~~~~~i
~~ ~~~~i
~~~O
~~t
~:e
:~t
~~~~
ppying 0 Focilities Charge to the Comoony.
=~~~~::r~~~ :~C~:i~~:e~ond the Point of Delivery will ~e set forth i~ 0 Djs!~~ution Focilities
~~t
~ ~
d~ ~domer As the Comoonv s Investment In Foclhtle5 Beyond the
~~~.~ ~~;"'
~~~i~:~~~;
~~ ~=
to ~;~vide the c~stomer s s ~ice reQ~irements. the Company shoO
Ions ond/(:)~ deletions of facIlIties by forwarding to the customer c
revise~ Distribution Focilities Investment Report.
In the event the Customer requests the Comoonv to remove or reinstall or change ~ompony-
~;~:~:~~~t~
~~i~~
~; ~~~~~
~ D~livery. the Customer sholl pay to the Comp~m~ the "~on-
~~
II f r m a I S lIotlon or change. Non-solvable ~ost as used herein IS compnsed
~: ;;:-:-f~;
~~~~~~;;
~~~m
~k.I"b'" anq g~eg~ of !he fa~lIIij~. ",p '~e difference ~e~t f te ~d and removallobor cost Including oppropnote overhead costs.
POWER FACTOR
~ere the Customer s Power Foetor is less then 85 percent. os d~termined by measurement
~'::~ ~~
b~~~~i~ i~~:~ns.
th~ Componv may adjust th: ~V'!
measured to determine the Billing
~eosured kW by 85 oercent end dlvldlno by the actual Power Foctor.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRill. IPca
PAGE 2 OF 13
t.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 91-
SCHEDULE WG-.9 - INTERIM
LARGE GENERAL SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Char.ge is the sum of the Customer. Basic. Demand
at the following charges EiEHF\J3l:4ted at tRe felle'Ning rates:
Energv. ond Facilities Charges
Customer Charge
15.50 cer month
Basic Charge
10.00 oer kW of Basic Load Caoacitv
Demond Charae
$3..5i3:22 per kW for all kW of Demond
Enerav Charae
Power Cost
Adiustmenf8'
0.1449~
Effective
Rate
2.Z6Qi Q795~per kWh for all kWhBose Rate
61 602.93 4 &~
Facilities Charge
~~i;~~t;~~rn~mum Charge shall be the sum of the Customer Charge. the Basic Charge the
Demond Charoe and the Enerav Charges& fer tRe meAth. 91:4t Aet less than $15.00.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bnl rendered for service supplied hereunder is payable upon receipt. and becomes
post due fifteen (1 ~ days from the dote on which rendered.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRIU. IPCO
PAGE 3 OF 13
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 191-
SCHEDULE NG-.19 - INTERIM
LARGE POWER SERVICE
AVAILABILITY
Service under this schedule is available at points on the Company s interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service. those facilities
provided for under Schevdle 71 Rule will be provided under the terms and conditions of that schedvle
wla. To the extent that additional facilities not provided for under SsAedvle 71 Rule H.including
transmission and/or substation facilities. are required to provide the requested service. special
arrangements will be made in a separate agreement between the Customer and the Company.
Each Customer is required to enter into a Uniform Large Power Service Agreement prior to being
served under this schedule.
APPLICABILITY
Service under this schedule is applicable to Customers with firm electric demand of 750 to 25.000
kilewa~tleW~ at a single Point of Delivery who have entered into a Uniform Large Power Service
Agreement. If the aggregate power requirement of a Customer who receives service at one or more
Points of Delivery on the same pfremises exceeds 25.000 IeW. the Customer is ineligible for service under I
this schedule and is required to melee special contract arrangements with the Company.
This schedule is not applicable to service for resale. 1Q..shared ,eNise. S2I-,irrigation service.
!g
stcndby or supplementcl service unless the Customer hcs entered into c Uniform Stcndby Service
Aoreement with the Comccnv.or !g.multi-family dwellings.
SERVICE ELIGIBILITY
To be eligible for initial service under this schedule. a Customer must register a metered demand
of 750 JeW or more under one of the Company s other FEHe-schedules for at leost three Billing Periods I
during the Customer's Annual Review Period. A Customer who meets this metered demand criterion
can be transferred to this schedule effective with the Billing Period immediately following eligibility
crovided the Customer enters into a Uniform Large Power Service Agreement with the Company.
The rates and charges provided for in this schedule will be billed beginning with the first Billing
Period during which service is provided under this schedule.
Continued Eliaibilitv.To be eligible for continued service under this schedule. a Customer's
metered demand at a single Point of Delivery must equal or exceed 750 JeW for at leost three Billing
Periods during the Customer's Annual Review Period.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPce
PAGE 4 OF 13
LP.C. NO. 26. TARIFF NO. 101 INAL HEET N . 191-
SCHEDULE NG--.19 INTERIM
LARGE POWER SERVICE
(Continued)
TYPE OF SERVICE
The Type of Service provided under this schedule is sinole and/or three-phase at approximately
60 cycles and at the primary ~tandard service voltage available at the pfremises to be served. byt not
less tASA 12.5 kilovolts
POI~1t OF DELIVERY
The Point of Delivery is the point where the Compsny s lines fiFst become seijscent to the
Cystomer's proper?,'.
ANNIVERSARY DATE
The Anniversary Dote is the date on which initial service is token under this schedule.
For each Customer ~receiviAge.d service under this schedule prior to January 1. 1993. the
Anniversary Date will be iL.the Customer's GYFrent review dote set forth in the Company s records end
used as of January 1. 1993. for the Annual Review Period.
ANNUAL REVIEW PERIOD
The Annual Review Period is the twelve12-month period ending with the Bil6ng Period in which
the Customer's Anniversary Date falls. Each year. at the end of the Annual Review Period. each
Customer's account will be reviewed for continued service eligibility under this schedule. Customers
who do not meet the Service Eligibility provisions will be transferred to the appropriate FEHe-schedule
effective with the next Billing Period and the Uniform Lorge Power Service Agreement will be canceled.
Customers who can document that they will no longer be eligible for continued service under
this schedule as a result of installing conservation measures. may. upon application to and approval by
the Company Vice President of Distnbution. be transferred to a different ~schedule prior to the end
of the Annual Review Period and the Uniform Large Power Service Agreement will be canceled.
BASIC lOAD CAPACITY
The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period. but not less than 750
kW.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRIU. IPCO
PAGE 5 OF 13
LP.. N . 2 TARIFF N . 101 ORIGINAL SHEET NO. 191-
SCHEDULE NQ-.19 INTERIM
LARGE POWER SERVICE
(Continued)
BILLING DEMAND
The Billing Demond is the overage kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period. adjusted for Power foetor. but not less than 750 kW.
FACILITIES BEYOND THE POINT OF DELIVERY
At the option of the Company. transformers and other facilities beyond the Point of Delivery
may be owned. operated. and maintained by the Company in consideration of the Customer paying
a Facilities Charge to the Company. '
Company-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Facilities
Investment Report provided to the Customer. As the Company s investment in Facilities Beyond the
Point of Delivery changes in order to provide the Customer's service requirements. the Company sholl
notify the Customer of the additions and/or deletions of facilities by forwarding to the Customer a
revised Distribution Facilities Investment Report.
In the event the Customer requests the Company to remove or reinstall or change Company-
owned Facilities Beyond the Point of Delivery. the Customer sholl pay to the Company the "non-
solvable cosf' of such removal. reinstallation or change. Non-solvable cost as used herein is comprised
of the total oriQinal costs of materials. labor and overheads CGsts o installing the facilities. less the
difference between the solvable cost of material removed and removal labor cost including
appropriate overhead costs.
POWER FACTOR ADJUSTMENT
Where the Customer's Power Factor is less than 8~ percent.as determined by measurement
under actual load conditions. the Company may adjust the kW measured to determine the Billing
Demand by multiplying the measured kW by 85 percent and dividing by the actual Power Factor.
TEMPORARY SUSPENSION
When a Customer has property invoked General Rule f23. Temcorarv Suscension of Demond
the Basic Load Capacity and Billing Demond shall be prorated based on the period of such suspension
in accordance with General Rule f23. In the event the Customer's metered demand is less than 750 kW I
during the period of such suspension. the Basic Load Capacity and Billing Demond will be set equal to
750 kW for purposes of determining the Customer's monthly Minimum Charge.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPce
PAGE 6 OF 13
I.P.C. NO. 26. TARIFF NO. 101 INAL ET N . 191-
SCHEDULE NG-.19 - INTERIM
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer.Basic. Demond. Energy. and Facilities Charges
at the following rates:
Customer Chafge
$85.00 per month
Basic Charge
10.76 oer kW of Basic Load Capacitv
Demond Charge
13.04 per kW for all kW of BillinQ Demond
Enerov Cha~e Effective
Rote
21916C!!
Power Cost
Adjustment*
0 1449C!!
~~~~;~te oer kWh for all kWh
Facilities Charae
CAe ans 'eOo'eR tentt.~s perseRt (l.7CJt) time, tlhe Company s investment in Company-owned
Facilities Beyond the Point of Delivery times 1.7 oercent
Hiah Voltoae Credit - (When service is token at 44 kV or above)~per kW for all kW of Billing Demand
~~~
The monthly Minimum Charge shall be the sum of the
Customer Choroe. the Basic Charge. the
Demand Charge. the Energy Charge. and the Facilities Charge. The Demand Charge would be
reduced by a High Voltage Credit if applicable.
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
The monthly bill for service supplied hereunder is payable upon receipt. and becomes past due
15 days from the date. on which rendered.
EXHIBIT NO.
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 7 OF 13
LP.. N 26.TARIFF N . 1 ORIGINAL SHEET NO. 241-
SCHEDULE ~24 - INTERIM
IRRIGATION SERVICE
AVAILABILITY
Service under this schedule is available Agt points on the Company s interconnected system
)Yithin the State of Idaho for loads up to 25.000 kilawatis where existing facilities of adequate
capacity and desired phase and voltage are adjacent to the ~fremises to be served. and additional
investment by the Company for new transmission. substation or terminal facilities is not necessary to
supply the desired service. If the aggregate power requirement of a Customer who receives service
one or more Points of Delivery on the same ~fremises exceeds 25.000 kW. special contract I
arrangements will be required.
Service under this schedule is not available to Blackfoot District Customers during the term of the
Blackfoot District Irrigation Service Pilot Program. Schedule 24-Pilot. and Blackfoot District Customers
desiring irrigation service are required to take service under Schedule 24-Pilot. Blackfoot District
Customers have account numbers which include "72" in positions three and four (e.g.. 0072-000000-0).
The Blackfoot District Irrigation Service Pilot Program is effective beginning September 1. 1994 and
terminating October 1. 1996 with the exception that THE "LATE PAYMENT" AND "SEASONAL ADVANCE"
PROVISIONS OF SCHEDULE 24-PllOT WILL BE APPLIED TO ANY BLACKFOOT DISTRICT IRRIGATION
CUSTOMER'S MONTHLY BILLS RENDERED UNDER SCHEDULE 24 DURING 1994 PRIOR TO SEPTEMBER 1. 1994.
APPLICABILITY
Service under this schedule is applicable +10 power and energy supplied to farm customers and
organizations at one Point of Delivery and through one meter for the operation of irrigation pump
motors. The Company will connect service and disconnect service once each calendar year without
charge during normal business hours. For all other customer requested connections or disconnections
the Customer will pay the actual expense incurred whether or not the additional connect or disconnect
is performed during normal business hours.
SEASONAL DEFINITION
The Irrigation. Season will begin with the Customer's meter reading for the May Billing Period and
end with the Customer's meter reading for the Septerraber Billing Period. The beginning cycles of a
Billing Period may actually be based on meter readings taken not more than ZseYeA days prior to the I
start of the corresponding calendar month. .
TYPE OF SERVICE
The tyee of service orovided under this schedule is S$.ingle and/or three-phase. alternating
current. at approximately 60 cycles and at the standard voltage available at the ~fremises to be
served.
~~~I
~ey Be meterea aA tRe lev! tenslen slae af CI:o/damer's tr'ander:meFS. in whiGA event
measI:o/rement '.-"AI Be aSjl:o/dea fer tFemfaFmer lesse5.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRIU. IPca
PAGE 8 OF 13
I.P.C. NO. 26. TARIFF NO. 101
BASIC LOAD CAPACtTY
INAL SHEET N . 241-
SCHEDULE NO-. 24 - INTERIM
IRRIGATION SERVICE
(Continued)
!be Basic Load Capacity is the average of the two greatest non-zero monthlv metered demands
~~t~~iSh~~~~~ri~~ th; 12-;~nth ceriod beginning with the November BillinQ Period and ending with the
II ing O~tober BillinQ Period The B05ic Charge is acplied to the B05ic Load Capacity.
The Basic Load Ca~ac:ity is calculated each month when the monthly bill is crepared For the
~~ ~:~ ~;ma
;~~ ~~ri
~ ~:~
12-month period beginning with the Noyemb~r Billing Period. the Basic
;~~ h- ~- :d't~
~;;
~~t ~f the Basic Load Capacity. For each subsequent bill durinQ the 12-
e . . e B i ~;~e is apclied to the difference between the Basic Load Ccpacity
r~~~t~d
~tth~ time the CUrTent bill is crepared aDd the B05ic Load ~agcc:ity qgainst which the Basic
th~~:~5~~i~~~i
b~;~~~li~d~ The follo;,ina example iIIustrcte:s th~ comcutation of and bi1lin
~ .
forac s :;I~g the first bill for the 12-month ceDQd I~ t:2~parep for the March Billing
Period:
Billing
Month
Metered
Demand
March 100 JeWApril 150 JeWMay 150 JeW June 150 JeWJulY 150 JeWAugust 125 JeW
Annual Amount
BILLING DEMAND
Basic Load
Capacitv
B05ic Load Copa~
Billed the B05ic Charge
100 JeW
125 JeW
150 JeW
150 JeW
150 JeW
150 JeW
150 JeW
50 JeW (100 JeW 50%)
75 JeW 1125 JeW 50 JeW)
25 JeW (150 JeW 125 JeW)
0 JeW 1150 JeW 150 JeWI
0 JeW 1150 JeW 150 JeWI
0 JeW 1150 JeW 150 JeW)
150 JeW
!be Billing Demand is +lhe average kW supplied during the 15-consecutive-minute period of
maximum use during the meter Feaging Bmina peeriod, adjusted for Power Factor.PROVIDED That at 1b.a
Company s option the Billing eQemand of a single motor installation of horsepower and less may be
:~~~e nwmber ef kilewatts equal to the number of horsepower but not less than one kW. When
or's Pewer Faster IS less ""taA Si per:eent legging. as aetem:llned t' meesWFement wnGer
~;twet leaa cenditiens. the Cempan,! may eajwd the JeW to determine tne Demand g', mwltiplying the
measwreg kW by Si ana gi'JiEtiRg b', the aEitwel Pewer Facter:. Metered power demands in knowatts
which exceed 13~ percent of the total connected horsepower served through one Point of
DeliveryserviEie EieRnectien will not be used for billing purposes unless and until verified by field test
the presence of the Customer to be the result of normal pumping operations. If a demand in excess
13~ percent of the connected horsepower is the result of abnormal conditions existing on the I
Company s interconnected system or the Customer's system. including accidental equipment feilure or
electrical supply interruption which results in tbLtemporary separation of the Company~ end !bA
Customer's system. the e.B.illing eDemand shall be 13~ percent of the connected horsepower. The
Customer may appeal the Company s billing decision to the Idaho Public Utilities Commission in cases
of dispute.
EXHIBIT NO.
CASE NO.IPC-94-
M. BRill. IPce
PAGE 9 OF 13
LP.C. NO. 26. TARIFF NO. 101 INAL . 241-
SCHEDULE NG-. 24 - INTERIM
IRRIGATION SERVICE
(Continued)
fACILITIES B~YOND THE POINT Of DELIVERY
~:he ~p
:~: ~: ~: ~~~~~~~.
transformers and oth~r focilities be:yond the Point of Delivery
moy be
-- _. _- __--_~
Inep by the Companv In conslde(a1l9n of the Customer payinQ
a facilities Charge to the Comca~
~~III~:~-O:':~ :Cf~I
~~:~~~~;
PQjl)t of OerNeoy wfll ~e set IQI'Ih i~ a (')~~~uflon FacQlijes
~~\~~
= :"c~~c
r ~ the Company's ,~v~meat In ~CCllltles Beyon~ the
~~~:~~;~,;;~~'t~::~:;~~~-
:~d~ the C:ustomefs s~i~e requ~me~ts. the C:omccnv sheD
lor deletions of foclhtles by forwarding to the Customer a
revised Distribution facilities Investment Report.
~~~ :e
~;~
Customer requests the Company to remove or reinstall or change Compa~
:':::1 F
~~~~~ ~~!.!L,:t~~ r:t ~ ~~~~c
tho: C~Iomer sholl goy 10 Ibe coml2!'~v Ihe '~on-
::','=:~ ~' ~ ~
al . 51 lieu ha~Qe. Non-solvable ,;osl '" woad hereIn IS I'amg",ed
~::
~;~~l ;~. ~:=:::i
:~
~n\i OYe~egds o( !be fc~mtil1s. less I~e ~iffe(!1nce bl'tweecle r ~ovallabor cost IncludlnQ aQP(Q~rJa~ overhead costs.
POWER fACTOR ADJUSTMENT
~ ~ ~~:;;~
Power foetor is less than 85 cercent as determined by measurement
:~e;; ~~
~~~ ~ 'jj",:-
~: If. ~~:-rg/,y m~ oqjust tb~ ~~ meosu(I'd 10 pelenT\ine lt1e aminoy n by 85 ce~cent and dlVldlnQ by the octuol Power Factor.
MONTHLY CHARGE
Basic Charge
$000 cer kW of Bosic Load Copocitv cer year
Customer Basic. Demand. Energy. aod Facilities
The Monthly Chorges is the sum of the
ChargeschaFges camp1;lted at the following rates:
C:ustomerChorge
S 1 0.00 Der month
Demand Charae
$~
per kW of ~illing Demond
No Demand Charge
Irrigation Season
Out of Season
EXHIBIT NO.
CASE NO. IPC-94-
M. BRIll. IPca
PAGE 10 OF 13
I.P.. N 26.TARIFF N . 1 ORIGINAL SHEET NO. 241-
SCHEDULE 24 - INTERIM
IRRIGATION SERVICE
(Continued)
MONTHLY CHARGE (Continued)
Enemv Cheree
Power Cost
Adiustment-
14491t
14491t
Effective
Rete
per kWh Irrigation Season
per kWh Out of Season
Bese Rate
2.aJ2..Z2. &84 51t
3.6l!Z 4 1721t
Hieh Voltaae Credit
When a Customer contracts for 100 kW or more and tokes service at 44.000 volts or higher. and
the Company provides no transformation equipment. the following credit will apply to those
Billing Months when kW of .Bil1iDg,.Demand is metered and billed.
$59.00 103 00 for the first 100 kW of a.illiDsLDemand. plus
l.QJ per kW for all additional kW of
Billing Demond
Minimum ~harae
IJ"Ie mont v MTnimum Charge sholl be the sum of the Customer Charge. the Basic ~harge. the
Demond Charge. and the EnerQV Charge.$l 5.00 per eeRAeQtee menth
This Power Cost Adjustment (Schedule 55) and this Effective Rate expire May 15. 1995.
PAYMENT
All monthly billings for eflectric sService supplied hereunder are payable upon receipt. and
become post due 15 days from the dote on which rendered.
1. MonthlY Cosh Advances: A monthly cosh advance equal to the current .taRf:Hate times I
the peak monthly use based on previous usage history for that account and for that Customer
will be required from:
An advance payment for irrigation Ceustomers is required under the following conditions:
a. Customers that did not pay all of their monthly billings on or before the post due
dote. but paid their final bill on or before the post due dote for the previous season.
b. Customers who were required to pay a seasonal advance for the previous
season. THI~ PROVISIO~IIS ~IOT ifFiCTIVi UHfil THi 19$11IRRICJ.TIO~1 SiASO~.
The monthly cash advance will be applied to the Customer's final bill for that season.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 11 OF 13
I.P.C. NO. 26. TARIFF NO. 101 INAL HEET N . 241-
SCHEDULE 24 - INTERIM
IRRIGATION SERVICE
(Continued)
PAYMENT (Continued)
2. Seasonal Advances:Customers that did not pay their final bill on or before the post due
date for the previous season will be required to pay a seasonal cosh advance, or provide
guarantee of payment from an acceptable bonk or financial institution located in the
Company s service territory. The seasonal cash advance will be applied to the Customer's
account upon receipt and the Customer's monthly billings will be deducted from the seasonal
advance as they occur. The seasonal advance for a specific installation will be computed as
follows:
The charge for the electrical usage at current rates for the specific installation.. less the
amount of the tax refund. based on the previous year's data. The advance may be
modified due to a change in crops.
3. New Customer.A seasonal odvance may be required for a new account at the
Company s discretion. The seasonal advance will be computed using the following formula:
a. Monthly Billing Demand (billing kW) will be determined by multiplying 80 percent I
times the connected horsepower.b. Monthly Energy (billing kWh) will be determined by multiplying 80 percent times
720 hours times the Monthly BiUicg.,Demand. c. The BillinQ Demand and the Energy volues are multiplied by the current rates to
determine the estimated monthly bill.d. The estimated monthly bill will be multiplied by the number of months appropriate
for the Customer's crop (up to a maximum of 4 months).
4. BankNctcv or Receivershic: An adequate assurance of payment as agreed to by the
utmty or as may be ordered by a court of competent jurisdiction or the IPUC, sholl be required
from any Csustomer for whom on order for relief has been entered under the federal I
bankruptcy lows, or for whom a receiver has been appointed in a court proceeding. The
maximum amount required for each season shall not exceed a payment equal to a seasonal
advance. For each irrigation season, on adequate assurance of payment sholl be required as
agreed to by the utility, or as may be ordered by a court of competent jurisdiction, or the IPUC.
This requirement sholl continue from the dote of the order for relief in bankruptcy, or the court'
order appointing a receiver, until the debtor's discharge in bankruptcy or the dismissal of the
court proceeding. A Csustomer who has been discharged from' bankruptcy or whose I
receivership proceeding has been terminated will be required to pay an advance at the start
the following. season to the extent required by the payment provisions listed under the other
"Paymenr sections of Schedule 24 - INTERIM
EXHIBIT NO. 43
CASE NO.IPC-94-
M. BRill, IPCO
PAGE 12 OF 13
I.P.26.TARIFF N . 1 ORIGINAL SHEET NO. 241-
SCHEDULE 24 - INTERIM
IRRIGATION SERVICE
(Continued)
INTEREST PAYMENTS
Interest will be credited by the Company on irrigation advances required under this schedule ot
the annual percentage rote of 8 percent. Interest will be computed ot 0 periodic daily rote (onnuol
percentage rate divided by 365 days) end will not accrue prior to Morch 15 or offer November 15 of
each year. All irrigation advances held by the Company will be refunded with interest on or before
November 15 end mailed to the Customer's last known address within 10 days.
MonthlY Advonce:For those Customers who hove mode 0 monthly advance. interest
will be credited to the Customer's account when the advance payment is applied
against the Customer's fino I bill for the season.
Seasonal Advance For those Customers who hove mode 0 seasonal cosh advance.
interest will accrue monthly on only that part of the seasonal advance which remains
offer deductions.
Eoch irrigation Customer. upon making 0 seosonal or monthly advance payment. will be required to
furnish to the Company on IRS Tox ID or Social Security number for the Company s IRS reporting requirements.
If 0 Customer tenders to the Company on irrigation advance which hos not been requested
demanded by the Company. the Company may refuse to accept end retain such advance. If. however.
the Company accepts or retains the advance. the Company wDl not pay interest on the irrigation advance.
LATE PAYMENT CHARGE
A Lote Payment Charge WIll be ossessed Schedule 24 - INTERIM Customers os provided under
Schedule 66.Gener:e1 R\:Ile dO sr CeRerol Rvle 31. whicAever i!; appAsoble.
EXHIBIT NO. 43
CASE NO. IPC-94-
M. BRill. IPCO
PAGE 13 OF 13