20070920Schwendiman direct.pdf

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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AND CHARGES FOR ELECTRIC SERVICE
TO ELECTRIC CUSTOMERS IN THE STATEOF IDAHO.
IDAHO POWER COMPANY
DIRECT TESTIMONY
CELESTE SCHWENDIMAN
IPC-O7 -
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Please state your name and business address.
Celeste Schwendiman andname
business address is 1221 West Idaho Street, Boise, Idaho.
whom employed and whatareyou
capaci ty?
I am employed by Idaho Power Company (the
Company) as a Senior Pricing Analyst in the Pricing and
Regulatory Services Department.
Please describe your educational background.
I received a Master s Degree in Business
Administration from Northwest Nazarene University and a
Bachelor of Arts Degree in Psychology from Eastern Oregon
University.I have attended the Center for Public Utilities
and National Association of Regulatory Utility
Commissioners ' Practical Skills for a Changing Utility
Environment conference, the Current Issues conference, and
the Edison Electric Insti tute ' s Electric Advanced Rate
Course.
Please describe your work experlence with
Idaho Power Company.
I was hired by Idaho Power Company in 1997 as
a Research Assistant II in the Pricing & Regulatory Services
Departmen t .I have been promoted as follows: February 1998,
Entry Analyst; August 1998, Analyst; and July 2001, Senior
Analys t .From 1998 through 2004, I assisted in the
SCHWENDlMAN, DI
Idaho Power Company
preparation of the Power Cost Adjustment (PCA) filings.
2005, 2006, and 2007, I sponsored testimony in the Company
annual PCA filings.In 2005, I sponsored the jurisdictional
separation study exhibits and testimony in case number IPC-
05-28, the Company s general rate case.In 2 0 0 6,
sponsored testimony in case number IPC-06-, the
Company s request to recover the costs resulting from a
purchase power agreement.
What is the scope of your testimony in this
proceeding?
I am sponsoring testimony in this proceeding
on the Idaho jurisdictional revenue requirement resulting
from the Jurisdictional Separation Study (JSS).
testimony is outlined as follows:
First, I am offering testimony summarizing
the adjustments to the forecasted total system 2007 test
year data used by the Company for purposes of restating the
Company s rate base, revenues, and expenses for the twelve
months ending December 31, 2007.Second, I am offering
testimony relative to a jurisdictional separation study
prepared using the adjusted 2007 total system data for
determining the Idaho jurisdictional revenue deficiency.
Finally, I am offering a 2008 test year and jurisdictional
separation study which shows a 2008 Idaho jurisdictional
revenue deficiency, even if the Company s request in this
SCHWENDlMAN, DI
Idaho Power Company
case is granted without adjustment.
Have you prepared exhibits for this
proceeding?
Yes,I am offering the following exhibits:
Exhibi t 20, Summary of Total Rate Base and
Net Income Adjustments
Exhibit 21 , Summary of Adjustments - Electric
Plant in Service
Exhibi t 22, Summary of Adjustments -
Accumulated Provision for Depreciation & Amortization
Exhibit 23, Summary of Adjustments -
Additions & Deductions to Rate Base
Exhibi t 24 , Summary of Adjustments
Operating Revenues
Exhibit 25, Summary of Adjustments
Operation & Maintenance Expenses
Exhibit 26, Summary of Adjustments -
Depreciation & Amortization Expense
Exhibit 27, Summary of Adjustments - Taxes
Other than Income Taxes
Exhibit 28, Summary of Adjustments - Income
Taxes
Exhibit 29, Jurisdictional Separation Study -
Idaho Revenue Requirement
Exhibi t 30, Development of Jurisdictional
SCHWENDlMAN, DI
Idaho Power Company
Allocation Factors
Exhibi t 31 , Jurisdictional Separation Study
(2008 )
please describe Exhibit 20.
Exhibit 20 consists of 2 pages and identifies
the development of the adjusted total electric system rate
base and the development of net income for the twelve months
ending December 31 , 2007.The values contained in column 1
are unadjusted 2006 actual values.The values contained in
column 2 are the 2007 forecast values.The adjustments
proposed by the Company for purposes of developing the 2007
adjusted total electric system combined rate base and net
income are shown in columns 3 through 5.The total sys tem
adjusted test year ratebase, expenses, and revenues are
summarized in column The test year values, except as
otherwise noted, were provided by Ms. Smith.
Page 1 of Exhibit 20 summarizes the
development of rate base components for the twelve months
ending December 31 , 2007.The total combined rate base
prior to test year adjustments was $1 999,832,858 (column 2
ine 1 7) .After adjustment, the total combined rate base
increased to $2,037 016,677 (column 6, line 17).
Page 2 of Exhibit 20 includes the development
of the total system net income for the twelve months ending
December 31 , 2007.Operating revenues are summarized on
SCHWENDlMAN, DI
Idaho Power Company
line Total operating expenses are summarized on line 15.
please describe the total test year 2007 rate
base , expenses , and revenues found in column 2 of Exhibit
20.
Total , unadjusted test year amounts are
presented in column 2 of Exhibit 20.They are the 2007
forecast test year values provided by Ms. Smith with two
exceptions.The Power Supply Expense ($903,519,108, as
shown on page 2, 1 ines 20 through 27) was the 2006 year- end
account balance wi th a minor adjustment to include
$6,426,777 of 2007 revenue from the sales of energy for the
provision of transmission losses.A similar adjustment was
made to capture expenses associated with the purchases of
energy for the provision of transmission losses.The Power
Supply Expenses were further adjusted for weather
normalization as described later.
Why have the 2007 test period ratebase,
revenues, and expenses been adjusted?
Test year information was adjusted to reflect
known changes that will occur during the test period.Under
this proposal, rates will reflect the most current cost
information available at the time they become effective.
Please explain what types of ratemaking
adjustments were made for the development of the Idaho
jurisdictional revenue requirement.
SCHWENDlMAN, DI
Idaho Power Company
Three types of ratemaking adjustments were
made for the development of the Idaho jurisdictional revenue
requirement.First, normalizing adjustments were made to
the Net Power Supply Cost items, which are influenced by
weather.Normalizing adjustments are shown in column 3 of
Exhibit 20.
Second, annualizing adjustments were made to
reflect changes that occurred wi thin the test year , but need
to be incorporated for the full year.Annualizing
adjustments are shown in column 4 of Exhibit 20.
Third, other types of adjustments, such as
those resulting from past Commission Orders, were made to
the test year values.These types of adjustments are shown
in column 5 of Exhibit 20.
Please discuss the normalizing adjustments to
the rate base components summarized in Exhibit 20, page
column 3.
The normalizing adjustment made to the total
system rate base was a decrease of $1,766,228 to FERC
Account 151/Fuel Inventory, to reflect normalized operating
criteria resulting in required coal inventories of 250,000
tons at Bridger , 180,000 tons at Valmy, and 47,000 tons at
Boardman.Mr. Said provided this adjustment.
please discuss the annualizing adjustments to
the rate base components summarized in Exhibit 20, page
SCHWENDlMAN, DI
Idaho Power Company
column 4.
An annualizing adjustment of $11 691 821 was
made to represent a full year of costs for production plant
investment made during the test year period.Large
proj ects, that will be online and serving customers before
the end of 2007 , were treated as if they had been in place
for the entire year.This adjustment is shown on line
Similar annualizing adjustments were made for transmission
projects ($30,625,598, as shown on line 4) and general plant
projects ($2 538,462, as shown on line 6).The total
annualizing adjustment for the 2007 investment is
$ 4 4 , 855 , 881 , a s shown on 1 ine 7.
An adjustment of $1 164,242 was made to
accumulated provision for depreciation to capture the rate
base impact of the annualized adjustment to depreciation
expense, and an adjustment of $4,910 for the accumulated
amortization, annualized to the end of 2007.Ms. Smith
provided these adjustments.
Have you included any other adjustments to
rate base?
Yes, the additional adjustments to rate base
shown in Exhibit 20, page 1 , column 5 are: 1) a reduction of
024 213 to remove all but $738,557 of plant held for
future use as discussed by Mr. Said in this proceeding, 2) a
reduction of $2 626,938 to remove the pre-paid items that
SCHWENDlMAN, DI
Idaho Power Company
are not traditionally included in test year rate base, and
3) a reduction of $85,531 to subsidiary rate base associated
with an investment at the Company s Bridger plant that was
disallowed through Idaho Public Utili ties Commission Order
29505.The adjustments total $4,736,682 as shown on line
17.
Please recap the net effect of the
annualizing and other adjustments to rate base on page 1
Exhibit 20.
After the adjustments are included, the
adjusted total electric system combined rate base for the
twelve months ending December 31 , 2007, as shown on column
6, line 17 , is $2 037 016,677.This amount is $37 183,819
more than the unadjusted total in column
Please describe page 2 of Exhibit 20.
Page 2 of Exhibit 20 shows the development of
the adjusted total electric system net income for the twelve
months ending December 31 , 2007.
Please describe the Company s normalizing
adjustments to the net income components shown in page
column 3, of Exhibit 20.
The two normalizing adjustments in column
were adjustments to both test period revenues and expenses
to remove the impact of weather and temporary rate
adjustments from the Company s revenues and expenses.
SCHWENDlMAN, DI
Idaho Power Company
The first adjustment is an adjustment of
negative $106,112 573 (line 2) to the Company s system
opportuni ty sales revenue.The forecasted revenue was
adjusted to reflect the decreased level of opportunity sales
associated with the multiple historical water conditions
provided.The second adjustment was a $160,937 378
reduction to operation and maintenance expense to reflect a
net decrease in fuel and purchase power expense associated
with multiple historical water conditions as well as an
increase in QF expense.These adjustments were provided by
Mr. Said.
Please explain the annualizing adjustment to
the statement of income on page 2 , column 4, of Exhibit 20.
An annualizing adjustment was made to reflect
changes in revenue, occurrlng within the test year that
should be included for a full year.The adjustment of
$370,387 was the revenue credit for the 2007 investment as
previously discussed.This amount, as shown in column
was provided by Mr. Said.
Please describe the annualizing adjustments
made to the operating expenses of the Company.
The adjustment of $7 769,616 to operating
expenses , as presented on page 2 , column 4 , of Exhibit 20,
consists of the following four items: 1) annualized payroll
in the amount of $4,500,064 , 2) annualize incentive in the
SCHWENDlMAN, DI
Idaho Power Company
amount of $229,859, 3) 2008 salary structure in the amount
of $3,020,719; and 4) annualized property and liability
insurance, for the 2007 plant projects , in the amount of
$18,974.
An increase to depreciation expense of
328,483 was made to reflect 2007 annualized depreciation.
The third adjustment was an increase of $9,820 for the
amortization of limited term plant, and the fourth
adjustment was an increase of $180,693, to taxes other than
income taxes, to reflect the property tax impact of the
annualized plant additions.
Please explain the other adjustments
presented on page 2 , column 5, of Exhibit 20.
The adjustment of negative $15,732,910, shown
on line 3, was the removal of DSM rider revenues.
matching adjustment to remove DSM program expense was made
and the result creates a net zero impact to the test year
for the DSM programs.
The total adjustment of negative $20,624 092,
to operating and maintenance expenses, was for the removal
of: 1) DSM program expense of $15,732 910 as discussed
above, 2) pension expense of $4 607 443, 3) general
advertising expense of $115,013, 4) membership and
contribution expense of $209,911, and 5) office expense of
$9,464.The addition of $50,649 was made to include the
SCHWENDlMAN, DI
Idaho Power Company
authorized level of intervenor funding.Finally, an
adjustment of negative $1,427,334 , to exclude FERC account
536 expenses recovered through the Company s Power Cost
Adjustment (PCA).Ms. Smith provided all of the above
adjustments.
Please describe Exhibit 21.
Exhibi t 21 consists of two pages and provides
detail of the adjustments, by FERC account, to the Company
electric plant in service used in this proceeding.
please describe Exhibit 22.
Exhibi t 22 consists of two pages and provides
detail of the accumulated provision for depreciation and
amortization reserve.
Please describe Exhibi t 23.
Exhibi t 23 consists of two pages and provides
detail of other additions to or deductions from the
Company s total combined rate base.
Please describe Exhibi t 24.
Exhibit 24 is a summary, by FERC account, of
the Company s operating revenues for the test period used in
this proceeding.
please describe Exhibi t 25.
Exhibi t 25 consists of six pages detailing
unadjusted and adjusted test year operation and maintenance
expenses for the twelve months ending December 31, 2007.
SCHWENDlMAN, DI
Idaho Power Company
Please describe Exhibit 26.
Exhibit 26 consists of two pages and provides
greater detailed information by FERC account of depreciation
and amortization expenses used in this proceeding.
Please describe Exhibit 27.
Exhibit 27 provides detailed information
regarding taxes other than income taxes and revenue credi
and debi ts used in this proceeding.
Please describe Exhibit 28.
Exhibit 28 consists of four pages and
provides a detailed summary of the income tax related
adjustments that result in the adjusted tax expenses on page
, lines 9 through 14, of Exhibit 20.The Company I s tax
department provided these adjustments.
Have you prepared an exhibi t that sets forth
the Idaho jurisdictional revenue deficiency?
Yes, I have prepared Exhibit 29 titled
Jurisdictional Separation Study - Idaho Revenue
Requirement" consisting of 3 6 pages.
Please discuss the methodology used to
jurisdictionally separate costs in the preparation of this
study.
The cost of providing electric service was
calculated using forecasted test year data and adjustments
for the twelve months ending December 31, 2007.
SCHWENDlMAN, DI
Idaho Power Company
A three-step process was used to separate
costs among jurisdictions.The three steps are
classification, functionalization, and allocation of costs.
In all three steps, recognition was given to the way In
which costs are incurred by relating these costs to utility
operations.The methodology used to separate costs by
jurisdiction and calculate the Idaho jurisdictional revenue
requirement in the present case was the same methodology
accepted by the Idaho Public Utilities Commission in
previous rate cases.
Would you please briefly explain the meanlng
of classification , functionalization , and allocation?
Classification groups costs into three
categories: demand-related, energy-related, and customer-
In addition to classification , costs arerelated.
functionalized; that is, costs are identified wi th utility
operating functions such as generation , transmission, and
distribution.Individual plant items are examined and,
where possible , the associated investment costs are assigned
to one or more operating functions.Once the Company
total system costs are classified and assigned to the
appropriate function they may be allocated among
jurisdictions.
The process of allocation is merely one of
apportioning the total system cost among jurisdictions by
SCHWENDlMAN, DI
Idaho Power Company
introducing allocation factors into the process.
allocation factor is nothing more than an array of numbers,
which specifies the jurisdictional value or share of the
total system quantity.For example, in the case of energy-
related costs, the allocation factor is annual
jurisdictional energy use, adjusted for losses.
Once individual accounts have been allocated
to the various jurisdictions it is possible to summarize
these into total utility rate base and net income by
jurisdiction.The results are stated in a summary form to
measure adequacy of revenues for the jurisdiction under
considera tion.The measure of adequacy is typically the
rate of return earned on rate base, which is compared to the
requested rate of return.
How have the various functional plant and
cost items been allocated?
The average of the twelve monthly coincident
peak demands was used to allocate the demand-related costs.
This allocation method has been used by the Company for the
past 25 years in all of its filings, regardless of
jurisdiction, requiring a jurisdictional separation study.
This allocation method was adopted by this Commission, and
accepted by the Oregon Public Utility Commission and by the
Federal Energy Regulatory Commission.The demand-related
allocation factors used in the study are designated as D10,
SCHWENDlMAN, DI
Idaho Power Company
D11, and D60.The respective values used in these demand
allocation factors are shown at line numbers 970 through 972
of Exhibit 30 "Development of Jurisdictional Allocation
Factors , the allocation section from the Company s JSS.
What method was used to allocate general
plant and certain labor-related administrative and general
expenses?
In accordance wi th FERC procedures, general
plant and administrative and general expenses were allocated
in accordance with functionalized wages and salaries.These
labor-related allocation factors are shown on lines 774
through 965 of Exhibit 30.
How were the energy-related expenses
allocated among jurisdictions?
Energy-related expenses were allocated based
on normalized jurisdictional kilowatt-hour sales, adjusted
for losses to establish energy requirements at the
generation level.The energy-related allocation factors
used in the study are designated as E10 and E99.The
respective values used in these energy allocation factors
are shown on lines 975 and 976 of Exhibit 30.
What was the method by which you allocated
customer-related costs?
The principal customer-related expenses,
which required allocation , were meter reading (FERC Account
SCHWENDlMAN, DI
Idaho Power Company
902), customer accounting, and billing (FERC Account 903) .
These accounts were allocated based upon a review of actual
Company practice of reading meters and preparing monthly
bills or statements.
Please describe the derivation of the 2007
total system allocation factors used in this case.
The allocation factors in the 2007
Jurisdictional Separation Study were based on 2006 year-end
data with some exceptions.The capacity or demand-related
allocation factors (D10, D11, and D60) were created using
the 5-year median demand ratios from the load research
sample applied to the 2007 test year energy.The energy-
related allocation factors were the 2007 test year load at
generation level (E10), and at customer level (E99).
Please describe Exhibi t 29.
Exhibi t 29 is the complete Jurisdictional
Separation Study detailing allocation of each component of
rate base, operating revenues, and expenses by FERC account
resul ting in the Idaho jurisdictional revenue deficiency.
The JSS is organized as follows:
Summary of Results
Table 1 - Electric plant in Service
Table 2 - Accumulated provision for
Depreciation (and Amortization)
Table 3 - Additions & Deductions to Rate Base
SCHWENDlMAN, DI
Idaho Power Company
Table 4 - Operating Revenues
Table 5 - Operation & Maintenance Expenses
Table 6 - Depreciation & Amortization Expense
Table 7 - Taxes Other Than Income Taxes
Table 8 - Regulatory Debits & Credits
Table 9 - Income Taxes
Table 10 - Calculation of Federal Income Tax
Table 11 - State Income Tax - Oregon
Table 12 - State Income Tax - Idaho and Other
Table 13 - Development of Labor Related
Allocator
Table 14 - Allocation Factors
Table 15 - Distribution Jurisdictional
Allocation
Table 16 - Allocation Factors-Ratios
Briefly describe the manner in which you
allocated electric plant in service as shown in Table 1 of
Exhibit 29.
production plant was allocated to all
jurisdictions based on the average of the twelve monthly
coincident peaks.The allocation of transmission and
distribution plant was based on the same methodology.
Would you describe the functional categories
used for allocation and direct assignment of transmission
plant and distribution substations?
SCHWENDlMAN, DI
Idaho Power Company
Transmission facilities are the facili ties
that form the bulk of the power transmission system together
with transmission , step-up substation facilities required to
introduce the Company s generation into the power supply
system and include facilities rated at 500kv through 46kv.
Distribution facilities refer to lower voltage lines and the
substation facilities that provide localized service.Some
transmission and distribution facilities were directly
assigned to the customers who paid for the exclusive use of
those facilities.
How have you allocated the accumulated
provision for depreciation and amortization of other utility
plant?
Accumulated provision for depreciation was
allocated among jurisdictions as shown on Table 2 of Exhibi
29.The accumulated totals for each type of production
plant and for each primary plant account in other functional
groups were allocated based on the related plant account as
allocated in Table Amortization of other utility plant
was functionalized and then allocated based on the related
plant items as allocated in Table
Please describe Table 3 of Exhibit 29.
Table 3 details the allocation of all other
addi tions to or deductions from rate base.Deductions from
rate base included the customer advances for construction
SCHWENDlMAN, DI
Idaho Power Company
that were directly assigned to the customers by
jurisdiction , and the accumulated deferred income taxes that
were allocated by plant.Additions to rate base included:
1) materials and supplies which were functionalized and
allocated by the respective plant allocators, 2) fuel
inventory that was allocated on the basis of energy,
components of IERCO, the Company s fuel subsidiary, which
were allocated based on energy, and 4) deferred investment
in Idaho conservation programs which was directly assigned
to the Idaho jurisdiction.
All rate base items , with the exception of
accumulated deferred income taxes and the investment in
conserva tion programs, reflect the average of ending
balances.
Please describe Table 4 of Exhibi t 29.
Table 4 contains the adjusted firm operating
revenues for each jurisdiction for the twelve months ending
December 31 , 2007.Opportuni ty sales represent non-firm
energy sales to other utili ties, which were credited to each
jurisdiction in proportion to generation-level energy use.
Other operating revenues were either
allocated among jurisdictions in a manner that offset
related allocations of rate base or, where a particular
revenue item could be associated with a specific
jurisdiction, directly assigned.
SCHWENDlMAN, DI
Idaho Power Company
Briefly describe the methods by which
operation and maintenance expenses were allocated.
The allocation of each operation and
maintenance expense is detailed on Table 5 of Exhibit 29.
In general , the basis for each allocation is identifiable
wi th the source code listed on the exhibi Demands are
identified by a source code beginning with a "D" prefix,
energy use is identified by a source code beginning wi th an
E" prefix , related plant is identified by a line number
source code, and customer-weighted allocation factors
beginning with a "CW" prefix.
In what manner are supervision and
engineering expenses treated throughout the allocation of
operation and maintenance expenses?
For the applicable expense account in each
functional group, the labor component was separately
allocated in accordance with the detail provided on Table
of Exhibit 29.The total of allocated labor in each
functional group became the basis for the allocation of
supervision and engineering expense.Total allocated labor
expense served the addi tional purpose of allocating employee
pension and other labor-related taxes and expenses.Table
13 of Exhibit 29 details the development of all the labor-
related allocation factors used in this study.
Please describe Table 6 of Exhibit 29.
SCHWENDlMAN, DI
Idaho Power Company
The allocation of depreciation expense and
amortization of limited term plant is set forth on Table
These expenses were identified by type of production plant
or by primary plant account for other functional plant
groups and allocated consistent with the related plant
account.
Please describe Table 7 of Exhibit 29, and
the allocation of taxes other than income taxes.
Taxes other than income taxes were treated
individually and allocated in a manner consistent with the
bases by which the respective taxes are assessed.
Please describe Table 8 of Exhibit 29.
Table 8 of Exhibi t 29 lists the regulatory
debi ts and credits for amortization of professional fees
authorized in Idaho Public Utilities Commission Order 29505.
However, no amounts were forecasted for the 2007 test year.
please describe Table 9 of Exhibit 29.
The expenses shown on Table 9 consist of
deferred income taxes and the investment tax credit
adjustment and were functionalized and allocated based on
total allocated plant.State and Federal income tax
liabilities are also summarized on Table The income
taxes shown on Tables 9 through 12 were obtained from the
Company s tax department.
please describe how you allocated Federal and
SCHWENDlMAN, DI
Idaho Power Company
State income taxes shown on Tables 9 through 12 of Exhibit
29.
Total income taxes were not allocated, per
Instead, the respective tax bases were developed, andse.
taxes were calculated directly for each jurisdiction.
Operating income before taxes represents adjusted operating
revenues less all adjusted operating expenses treated
heretofore with the exception of deferred income taxes and
investment tax credits.Adj us ted long- term and other
interest expenses were allocated by total plant to develop
net operating income before taxes.From that point forward,
addi tions to, or deductions from the respective tax bases
were allocated to each jurisdiction by net income before
In this manner, taxable income for each jurisdictiontaxes.
was developed, and the appropriate tax rate was applied.
Final tax amounts result after the allocation of adjustments
and tax credits.All details relating to the calculation of
Federal, Oregon , Idaho, and other state income taxes are
found on Tables 10, 11 , and 12.
Please describe Tables 13 through 16 of
Exhibi t 29.
Tables 13 through 16 of Exhibit 29 list the
principal allocation factors used in the study and the
respective jurisdictional values for each allocation factor.
Table 15 lists the ratios of the principal allocation
SCHWENDlMAN, DI
Idaho Power Company
factors included in Table 14.
please describe the development of the Idaho
Jurisdictional revenue deficiency.
The summary of results is presented on pages
1 and 2 of Exhibit 29.The development of the Idaho
jurisdictional revenue deficiency is presented in the column
enti tled "IDAHO IPUC" on page 1 of Exhibit 29.
The Idaho net income of $122,231,938 (line
26) resulted in a return on rate base of 6.49 percent (line
27) .Based upon the rate of return of 8.56 percent provided
by Mr. Keen, the Company s Idaho jurisdictional net income
should be $161 175,457 , as shown on line 32.The resulting
earnings deficiency was $38,943,519, as shown on line 33.
What net-to-gross or incremental income tax
factor did you use In developing the Idaho jurisdictional
revenue deficiency?
The composite incremental tax multiplier of
642 is the assimilation of the Federal effective tax rate
of 35 percent , an Idaho composite tax rate of 5.9 percent,
an Oregon composite tax rate of 0.3 percent, and an
addi tional state composite tax rate of 0.1 percent.This
value , as shown on line 35 of Exhibit 29, was provided by
the Company s Tax Department.
What is the resulting Idaho jurisdictional
revenue deficiency?
SCHWENDlMAN, DI
Idaho Power Company
The result of the Jurisdictional Separation
Study, as shown on page 1 , line 36 of Exhibit 29, indicate a
total revenue deficiency of $63,945,258 for the Idaho retail
jurisdiction.This represents a required 10.35 percent
increase in normalized Idaho jurisdictional revenues.
please describe Exhibit 31.
Exhibit 31 is the 2008 Jurisdictional
Separation Study.The 2008 study is comprised of the
available 2008 forecast information , processed using the
same methodology, as described on the preceding pages of
this testimony.The 2008 study does not include the
expected inclusion of additional. rate base for the Evander
Andrews Complex addi tion and Hells Canyon Complex license
renewal.These are large cost items that will need to be
addressed in 2008.
Is the Company requesting rate relief based
upon the revenue requirement results of the 2008
Jurisdictional Separation Study?
No, the Company is not requesting rate relief
based upon the 2008 study results at this time.However,
the 2008 study demonstrates that even if the Company
entire 2007 request was approved by the Commission without
change, the Company does not anticipate it would be able to
earn the authorized rate of return under normal conditions
in 2008.
SCHWENDlMAN, DI
Idaho Power Company
Does this conclude your testimony?
Yes, it does.
SCHWENDlMAN, DI
Idaho Power Company
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