20080919Dickman Direct.pdf

REceiVED
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lDAHO PUBLIC
UTtUTtES COMMiSSiON
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE )
APPLICATION OF ROCKY )
MOUNTAIN POWER FOR )
APPROVAL OF CHANGES TO ITS )
ELECTRIC SERVICE SCHEDULES )
AND A PRICE INCREASE OF $5.9 )
MILLION, OR 4.0 PERCENT )
CASE NO. PAC-E-08-07
Direct Testimony of Brian S. Dickman
ROCKY MOUNTAIN POWER
CASE NO. PAC-E-08-07
September 2008
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Q.Please state your name, business address and present position with Rocky
Mountain Power (the "Company"), a division of PacifCorp.
My name is Brian S. Dickman and my business address is 201 South Main, Suite
4 2300, Salt Lake City, Utah, 84111. I am currently employed as the Manager of
5 Revenue Requirement for the Company.
6 Qualifications
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Briefly describe your educational and professional background.
I received a Master of Business Administration degree from the University of
Utah with an emphasis in finance in 2002 and a Bachelor of Science degree in
accounting from Utah State University in 2001. In addition to my formal
education, I have also attended varous educational, professional and electrc
industry-related seminars. I have been employed by the Company since 2003
including positions in revenue requirement and regulatory affairs. Prior to joining
the Company in 2003, I was employed as an analyst for Duke Energy Trading and
Marketing.
What are your responsibilties as Manager of Revenue Requirements?
My primary responsibilities include the calculation and reporting ofthe
Company's regulated earnings or revenue requirement, application of the inter-
jurisdictional cost allocation methodology, and the explanation of those
calculations to regulators in the jurisdictions in which the Company operates.
Have you testified in previous regulatory proceedings?
Yes. I have testified before the Idaho Public Utilities Commission and the
Wyoming Public Service Commission.
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Rocky Mountain Power
1 Purpose of Testimony
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What is the purpose of your testimony in this proceeding?
My direct testimony addresses the calculation of the Company's Idaho-allocated
revenue requirement and the revenue increase requested in the Company's
application. In support of this calculation, I provide testimony on the following:
· Calculation of the $5.9 milion dollar revenue increase requested in this
case representing the increase over current rates required for the Company
to recover the costs required to serve Idaho customers not sered under a
tariff contract.
· A description of the test period proposed in this case; twelve months
ending December 31, 2007, with known and measurable adjustments
through December 31,2008 (the "Test Period").
· The adjusted results of operations for the Test Period demonstrating that
under current rates the Company wil earn an overall return on equity
("ROE") in Idaho of 6.5 percent, which is far below the return on equity
requested in this case and the current authorized return.
17 Revenue Requirement
18 Q.What price increase is required to achieve the requested return on equity in
19 this case?
20 A.Exhibit No. 12 includes a summar ofthe Company's Idaho-allocated results of
21 operations for the Test Period. At current rate levels, Rocky Mountain Power wil
22 ear an overall ROE in Idaho of 6.5 percent during the Test Period. This return is
23 significantly less than the 10.25 percent ROE included in the stipulation approved
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Rocky Mountain Power
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by the Commission in Case No. PAC-E-07-05 and is less than the 10.75 percent
return recommended by Company witness Dr. Samuel C. Hadaway in this
proceeding. An overall price increase of $19.4 milion would be required to
produce the 10.75 percent ROE requested by the Company in this proceeding.
Is the Company requesting the full $19.4 millon required to earn a 10.75
percent ROE?
No. The Company's request in this case is reduced for two reasons. First, the
rate mitigation cap as stipulated and approved by the Commission in Case No.
PAC-E-02-03 reduces the rate request by $3.1 milion as shown on page 1.0 of
Exhibit No. 12, resulting in a revenue shortfall of $16.3 milion. The stipulation
in Case No. PAC-E-02-03 states:
"For all Idaho general rate proceedings initiated after the effective date of
this Stipulation and Revised Protocol, and until March 31, 2009, the
Company's Idaho revenue requirement to be used for purposes of setting
rates for Idaho customers wil be the lesser of: (i) the Company's Idaho
revenue requirement calculated under the Rolled-In Allocation Method
multiplied by 101.67 percent, or (ii) the Company's Idaho revenue
requirement resulting from use ofthe Revised Protocol."
Second, pursuant to the stipulation approved in Case No. PAC-E-07-05 the
Company is not seeking to increase rates for tarff contract customers in this case.
The stipulation approved by the Commission calls for tarff rates for the
Company's two tariff contract customers in Idaho to be adjusted Januar i, 2009
and 2010, and the Company agreed to not make further adjustments to rates for
those contracts effective prior to January 1, 2011. This further reduces the rate
request by $10.4 milion.
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Rocky Mountain Power
1 Test Period
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What test period did the Company use to determine revenue requirement in
this case?
The Test Period for this application is based on the historical twelve-month period
ending December 31, 2007, adjusted for known and measurable changes through
December 31,2008.
Is the Test Period in this case consistent with test periods used by the
Company in previous Idaho general rate cases?
The Test Period is prepared consistent with past Commission practice and the
Company's general rate cases filed previously in Idaho. Additionally, as a result
of the significant capital investment being made and the regulatory lag associated
with it relative to the Idaho test year conventions, the Company has also relied on
and included rate base on an end-of-period basis as I wil explain further.
What guided the Company's development of the Test Period in this case?
The primary objective in determining a test period is to develop normalized
results of operations which best reflect the conditions during which time the new
rates wil be in effect. Multiple factors must be considered to determine which
test period best reflects these conditions. The Company believes that this is best
accomplished with a forecasted test period that coincides with the rate effective
perod. However, it is the Company's understanding that this method is not
currently allowed by the Commission. Therefore, the Company has relied on
historical data with known and measurable events to best reflect as closely as
possible the rate effective period that wil exist in 2009.
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Rocky Mountain Power
1 Q.Why is it important that the Test Period and the rate effective period be
2 aligned as closely as possible?
3 A.As explained by Mr. A. Richard Walje, the Company faces a rapidly changing
4 business environment and significant inflation in the cost to sere our customers.
5 During this period of rapid expansion and rate base growth, a historical test period
6 cannot adequately capture the conditions that the Company wil experience during
7 the rate effective perod; rather, it aggravates regulatory lag and constrains the
8 utility to chronically under-recover the true cost of servce.
9 Q.Has the Company made any adjustments to address regulatory lag related to
10 the Test Period in this case?
11 A.Yes. To partially overcome the effect of regulatory lag, the Company proposes to
12 include rate base on an end-of-period basis-actual rate base at December 31,
13 2007 plus major capital additions planned to go into service by December 31,
14 2008, reflected at the December 31,2008 balance levels. Adjusting to end-of-
15 period rate base provides more certainty while reducing the recovery lag
16 associated with the Company's significant capital investment. Including future
17 capital additions extending less than four months from the date of filing reduces
18 the exposure to movements in capital spending projections. In addition, all of
19 these capital additions wil be in service prior to the anticipated date of the price
20 change associated with this rate case.
21 Q.Do you have any further observations about the Test Period in this case and
22 the use of a future test period?
23 A.The Company now finds itself in a period where uncontrollable costs to meet
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Rocky Mountain Power
1 customer demand are increasing significantly. The Commission should require
2 consumers to pay a price that matches contemporaneously with the cost to serve
3 those customers. Any business that charges prices today that reflect two-year-old
4 costs wil always under perform. Although the use of a test period based on
5 historical data, known and measurable adjustments, and end of period rate base
6 does not give the Company the same level of cost recovery we would be
7 requesting in a forecast test period (since an historical period does not fully
8 synchronize the investment, revenues and expenses with the anticipated rate
9 effective period), under the facts and circumstances in this case it can support the
10 minimum level of costs that should be considered. A rate base, rate of return
11 regulated utility like Rocky Mountain Power must be given a reasonable
12 opportunity to earn its cost of capitaL.
13 Idaho Results of Operations
14 Q.Please explain how the Company developed the revenue requirement for the
15 Test Period.
16 A.Revenue requirement preparation began with historical accounting information; in
17 this case the Company used the twelve months ended December 31, 2007. Each
18 of the revenue requirement components in that historical period was analyzed to
19 determine if an adjustment was warranted to reflect normal operating conditions.
20 The historical information was adjusted to recognize known, measurable and
21 anticipated events and to include previous Commission-ordered adjustments.
22 As mentioned above, historical rate base is calculated using end-of-period
23 balances as of December 31, 2007. Major capital additions planed to go into
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Rocky Mountain Power
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service by December 31, 2008, are added based on the full cost expected to be
placed into service. In order to synchronize other components of the revenue
requirement, costs and benefits related to these major plant additions are included
in revenue requirement on an anualized level regardless of the date the resource
wil go into service in 2008. For example, the Marengo wind plant expansion
project went into service in August 2008. The capital cost ofthe project is
included in this case at the full amount, an anual level of operation and
maintenance expense is added, and the net power cost study assumes generation
from that project was available for a full 12 months.
Please describe Exhibit No. 12.
Exhibit No. 12, which was prepared under my direction, is Rocky Mountain
Power's Idaho results of operations report (the "Report"). The historical period
for the Report is the twelve months ended December 31, 2007, which has been
adjusted for known and measurable changes through December 31, 2008. The
Report provides totals for revenue, expenses, depreciation, net power costs, taxes,
rate base and loads in the Test Period. The Report presents operating results for
the period in terms of both return on rate base and ROE.
Please describe how Exhibit No. 12 is organized.
The Report is organized into sections marked with tabs as follows:
· Tab 1 Summary contains a summary of normalized Idaho-allocated
results of operations. Normalized results are allocated to Idaho as
prescribed by the Revised Protocol inter-jurisdictional allocation
method as approved by the Commission in Case No. PAC-E-02-03.
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Rocky Mountain Power
1 . Tab 2 Results of Operations details the Company's overall revenue
2 requirement, showing unadjusted costs for the year ended December
3 2007 and fully normalized results of operations for the Test Period by
4 FERC account.
5 . Tabs 3 through 8 provide supporting documentation for the
6 normalizing adjustments required to reflect on-going costs of the
7 Company. Each of these sections begins with a numerical summar
8 that identifies each adjustment made to the 2007 actual results and the
9 adjustment's impact on the case. Each column has a numerical
10 reference to a corresponding page in Exhibit No. 12, which contains a
11 lead sheet showing the adjusted FERC account(s), allocation factor,
12 dollar amount and a brief description of the adjustment. The specific
13 adjustments included in each of these tab sections are described in
14 more detail below.
15 . Tab 9 is Tab 2 restated with the Idaho allocation based on the Rolled
16 In allocation method. The Rolled In results are used to calculate the
17 rate mitigation cap adjustment on page 1.0.
18 . Tab 10 contains the calculation of the Revised Protocol allocation
19 factors.
20 Tab 3 - Revenue Adjustments
21 Q.Please describe the adjustments made to revenue in Tab 3.
22 A.Temperature Normalization (page 3.1) - This adjustment recalculates Idaho
23 revenue based on temperature normalized historical load assuming average
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1 temperature patterns.
2 Revenue Normalization (page 3.2) - This adjustment normalizes base year
3 revenue by removing items that should not be included to determine retail rates,
4 such as credits from the Bonnevile Power Administration ("BP A") for the
5 Residential Exchange Program. The expense side of the BP A credit is removed in
6 adjustment 5.6.
7 Effective Price Change (page 3.3) - First, this adjustment accounts for Schedule
8 19 biled cheaper revenues. Schedule 19 is closed to new service. During 2008,
9 149 customers served on Schedule 19 were moved to either Schedule 6 or 23
10 because the Company's analysis showed that their bils would be lower under the
11 new schedule. In addition, the Company proposes to move an additional 19
12 customers at the conclusion of this case. Moving these Schedule 19 customers
13 results in a small revenue decrease compared to the Test Period. Next, this
14 adjustment reflects the revenue increases as stipulated in Idaho Rate Case No.
15 PAC-E-07-05. An all pary settlement was reached and a stipulation filed with the
16 commission on November 6,2007. The stipulation was approved by the
17 Commission on December 28,2007, with an effective date of January 1, 2008.
18 Therefore, it is necessary to annualize the effects of a price change into results for
19 the 12 months ended December 2007.
20 Joint Use Revenue (page 3.4) - During 2007 several entries related to joint use
21 revenue were booked to incorrect FERC accounts and/or locations. This
22 adjustment corrects the accounting entries to reflect proper account assignment
23 and allocation factors.
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Rocky Mountain Power
1 Wheeling Revenue (page 3.5) - During 2007 there were varous transactions
2 regarding wheeling revenue that the Company does not expect to occur in the Test
3 Period. These transactions relate to various prior period adjustments and contract
4 terminations. This adjustment also includes pro forma wheeling revenue for the
5 12 months ended December 2008, including additional revenue for the Malin-
6 Indian Springs contract.
7 Green Tag Revenue (page 3.6) - In order to help meet jurisdiction specific
8 renewable portfolio standards, a market for green tags or Renewable Energy
9 Credits ("REC") is developing where the tag or green traits of qualifying power
1 0 production facilities can be detached and sold separately from the power itself.
11 Generally, wind, solar, geothermal and some other resources qualify as renewable
12 resources, although each state may have a slightly different definition. Currently,
13 California and Oregon have renewable portfolio standards that limit the
14 Company's ability to sell green tags. Therefore, this adjustment reverses actual
15 sales and allocates the sales for the 12 months ended December 2008 to the
16 remaining jurisdictions.
17 Clark Storage Revenue (page 3.7) - The Clark Storage & Integration
18 Agreement was terminated in December 2007. This adjustment removes the
19 revenue credit from the results of operations to reflect a normalized level of
20 ancilary service revenues.
21 S02 Emission Allowances (page 3.8) - Over the years, the Company's annual
22 revenue from the sale of sulfur dioxide ("S02") emission allowances has been
23 uneven. This adjustment removes the sales occurrng in the historical period and
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1 includes amortization of sales over a 15 year period.
2 Tab 4 - O&M Adjustments
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Please describe the adjustments made to O&M expense in Tab 4.
Miscellaneous General Expense (page 4.1) - This adjustment removes certain
miscellaneous expenses that should have been charged below-the-line to non-
regulated expenses.
Remove Non Recurring Entries (page 4.2) - Various accounting entries were
made during 2007 that were non-recurrng in nature or relate to a prior period.
This adjustment removes these items reducing total Company operating expense
by $2.5 milion. Details on the specific items in the adjustment can be found on
page 4.2.1.
Irrigation Load Control Program (page 4.3) - Incentive payments made to
Idaho customers paricipating in the irrgation load control program were system
allocated in unadjusted data. This adjustment corrects that allocation and assigns
these costs directly to Idaho consistent with other demand side management
("DSM") programs. This adjustment also recognizes a $5.4 milion increase in
total incentive payments in 2008 due to the stipulation approved in Case No.
PAC-E-07-05 and a significant rise in program participation. An offsetting
adjustment was made to reduce the jurisdictional load used to develop allocation
factors to reflect additional load participating in the program during the 2008
irrgation season. This load adjustment reduces Idaho load used to compute inter-
jurisdictional allocation factors and consequently the level of system-wide costs
allocated to Idaho. Details supporting the incremental load adjustment are
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1 provided on pages 4.3.2 and 10.14.
2 Blue Sky (page 4.4) - This adjustment removes costs associated with the Blue
3 Sky program that were initially included in regulated results. The Blue Sky
4 program is designed to encourage voluntary paricipation in the acquisition and
5 development of renewable resources. To prevent non-participants from
6 subsidizing the program this adjustment removes administrative and other
7 expenses directly associated with the program.
8 K2 Risk Management System (page 4.5) - The K2 risk management system
9 was capitalized during calendar year 2006; however, the project was written-off in
10 March 2007 because it was deemed not used and usefuL. This adjustment removes
11 the O&M expenses of the project and also removes the loss on the disposition of
12 the asset in account 421.
13 Generation Overhaul Expense (page 4.6) - Most ofPacifiCorp's generation
14 plants are on a four year maintenance cycle which can cause overhaul expense to
15 fluctuate year-to-year. This adjustment normalizes these costs using a four-year
16 average methodology. Actual overhaul expenses from 2004 - 2007 are escalated
17 to 2007 dollars using Global Insight indices and then those escalated expenses are
18 averaged. For the new Currant Creek and Lake Side generating units, the four
19 year average is comprised of the overhaul expense projected during the first four
20 years these plants are operationaL. The adjustment is calculated by subtracting the
21 actual overhaul costs from the escalated four year averages.
22 Preliminary Coal Plant Expense (page 4.7) - The Company was planning to
23 build three coal units: IPP unit 3, Bridger unit 5 and Hunter unit 4. On December
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1 6,2007, the Company announced that it would not presently pursue these
2 projects. The preliminary expenses the Company incurred for these abandoned
3 projects were written off to account 557. This adjustment removes these write-
4 offs from the results of operations.
5 Rent Expense (page 4.8) - This adjustment removes rent expense of unused
6 office space booked during 2007. It also corrects the allocation of sub-lease
7 income and annualizes the sub-lease rental income for agreements entered into
8 during 2007.
9 Wage & Employee Benefit Adjustment (page 4.9) - This adjustment is used to
10 compute labor-related costs for the Test Period. Labor-related costs for the Test
1l Period are computed by adjusting salares, incentives, benefits and costs
12 associated with FAS 87 (pension), FAS 106 (post retirement benefits) and FAS
13 112 (post employment benefits) for changes expected beyond the actual costs
14 experienced in 2007. Page 4.9.7 is a numerical summary starting with actual labor
15 costs in 2007 and summarizing the adjustments made to reflect the Test Period
16 level of expense. This summary is followed by the detailed worksheets used to
17 adjust the labor costs forward to the Test Period.
18 The first step to adjust labor is to annualize salary increases that occurred
19 during 2007. This was done by identifyng actual wages by labor group by month
20 along with the date each labor group received wage increases. The next step is to
21 apply the wage increases through December 2008 to the annualized 2007 salares.
22 The Company used union contract agreements to escalate union labor group
23 wages, while increases for non-union and exempt employees were based on
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1 budgeted increases. This calculation is detailed on pages 4.9.8 through 4.9.1 O.
2 Payroll taxes were updated to capture the impact of the changes to employee
3 salares.
4 An adjustment is also made to incentive compensation, pension expenses,
5 and other employee benefit costs expected to be incurred in 2008. The Company
6 utilizes an incentive compensation program as part of its philosophy of delivering
7 market competitive pay strctured in a manner that benefits customers with safe,
8 adequate and reliable electric service at a reasonable cost.
9 MEHC Transition Savings (page 4.10) - This adjustment removes the costs
10 associated with employees leaving under the MEHC transition plan and reflects
11 into results the future labor savings of eliminating positions. The deferral and
12 amortization ofMEHC transition costs is included consistent with the
13 Commission's orders in Case Nos. PAC-E-06-11 and PAC-E-07-05.
14 Incremental Generation O&M (page 4.11) - This adjustment adds incremental
15 operation and maintenance expense for the Lake Side plant, Blundell bottoming
16 cycle, and the Marengo wind plant, all of which were placed into service during
17 2007. Incremental O&M expenses are also added for generating units that were
18 not in service during the 12 months ended December 2007 but wil be in service
19 by December 31, 2008, including the Marengo II and Goodnoe Hils wind plants
20 and the Chehalis generating plant.
21 This adjustment also includes the impact of funding provided by the
22 Energy Trust of Oregon ("ETO") associated with Goodnoe Hils in exchange for
23 renewable energy credits allocated to Oregon customers after the first five years
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1 of operation. The amount of the funding included in the current case is $2,450,697
2 on a total Company basis. In this case Idaho can make an election to displace the
3 ETO funding and continue to receive an allocation of renewable energy credits
4 from the Goodnoe Hils facility after the first five years. If this election is made
5 then the amount of Idaho-allocated fuding wil need to be added to the Idaho
6 Test Period revenue requirement. If Idaho elects not to provide such funding,
7 Idaho wil forgo the right to receive an allocation of renewable energy credits
8 from the Goodnoe Hils facility after the first five years of the plant's operation.
9 MEHC Affiliate Management Fee (page 4.12) - This adjustment complies with
10 the MEHC acquisition commitment 128 which states:
11 "MEHC and PacifiCorp wil hold customers harmless for increases in
12 costs retained by PacifiCorp that were previously assigned to affliates
13 relating to management fees... This commitment is offsetable to the extent
14 PacifiCorp demonstrates to the Commission's satisfaction, in the context
15 of a general rate case the following:
16 i) Corporate allocations from MEHC to PacifiCorp included in
17 PacifiCorp's rates are less than $7.3 milion..."
18 This adjustment limits the MEHC corporate charge to PacifiCorp to $7.3 milion.
19 Postage Expense (page 4.13) - This adjustment reflects postage rate increases on
20 May 14, 2007 and May 12, 2008 for customer bilings.
21 Insurance Expense (page 4.14) - This adjustment normalizes injury and damage
22 expenses to reflect a three-year average of gross expense minus insurance
23 proceeds. This adjustment also normalizes property insurance expenses and
24 captive property and liabilty insurance expenses.
25 Compliance Department (page 4.15) - As of June 18, 2007, the electric utilty
26 industry has been operating under mandatory, enforceable reliability standards.
27 Utilities and other bulk power industry participants that violate any of the
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1 standards wil face enforcement actions including increased compliance
2 monitoring and testing requirements and/or possible monetary sanctions of up to
3 $1 milion per day. In order to comply with these enhanced reliability standards,
4 the Company anticipates the addition of 13 full-time employees as well as
5 increased program and information technology costs.
6 A&G Cost Commitment (MEHC) (page 4.16) - In Case No. PAC-E-05-08,
7 commitment 131 stipulated that PacifiCorp must reduce its administrative and
8 general expense below $222.8 milion, adjusted for inflation. This adjustment
9 demonstrates the administrative and general expense in the Test Period is below
10 the required leveL. For the time between approval of this commitment and its
11 reflection in rates, Idaho's share of $500,000 per month was deferred. As ordered
12 in Case No. PAC-E-07-05, effective January 1,2008, these savings are reflected
13 in Idaho rates. This adjustment amortizes the deferred balance over 3 years
14 beginning January 1,2008.
15 DSM Amortization Removal (page 4.17) - Idaho allows for recovery of DSM
16 expenses through the customer efficiency services rate adjustment (Schedule
17 191). This adjustment removes Idaho DSM costs in order to prevent a double
18 recovery through base rates and Schedule 191.
19 Memberships and Subscriptions (page 4.18) - This adjustment removes
20 expenses in excess of Commission policy as stated in Order No. 29505. National
21 and regional trade organizations are recognized at 75% and dues for membership
22 in Wester Electric Coordinating Council ("WECC") and Northern Tier
23 Transmission Group are included at 1 00%. All other membership dues are
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removed. The adjustment also recognizes an increase in fees for membership in
WECC beginning in 2008.
Idaho Intervenor Funding (page 4.19) - This adjustment amortizes previously
deferred intervenor funding over a period of one year.
Idaho Pension Expense Cash Basis (page 4.20) - This adjustment replaces the
actuarally determined pension expense for 12 months ended December 2007 with
the actual amount funded (cash basis). This adjustment is consistent with that
proposed in the Company's previous general rate case, Case No. PAC-E-07-05.
Did the Company make an adjustment for changes in workforce levels?
The wage and employee benefit adjustment assumes a constant level of
workforce. However, other adjustments account for minor changes in workforce
levels such as: 1) the labor savings from the reduction in the number of employees
due to the MEHC transaction was reflected in the MEHC Transition Savings
adjustment 4.10, 2) the additional costs from the increase in compliance staffng
as stated in the Compliance Deparent adjustment 4.15, and 3) wind generation
administration included in the Incremental Generation O&M adjustment 4.11.
17 Tab 5 - Net Power Cost Adjustments
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Please describe the adjustments included in Tab 5.
Net Power Cost Study (page 5.1) - The net power cost study adjustment
presents normalized Test Period steam and hydro power generation, fuel,
purchased power, wheeling expense and sales for resale based on the Company's
GRID modeL. It also normalizes hydro, weather conditions and plant availability
as described in Mr. Gregory N. Duvall's testimony.
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1 Green Tag (page 5.2) - This adjustment removes from regulatory results the cost
2 of green tag purchases made for the Blue Sky program.
3 West Valley Lease and Contract Term (page 5.3) - The Company terminated
4 the lease for the West Valley generating facilty on May 31, 2008, and this
5 adjustment removes the associated expense and rate base. This adjustment also
6 includes amortization of the deferred lease expense reduction for the Test Period.
7 James River Royalty Offset and Little Mountain (page 5.4) - On Januar 13,
8 1993, the Company executed a contract with James River Paper Company with
9 respect to the Camas mil, later acquired by Georgia Pacific. Under the
10 agreement, the Company built a steam turbine and is recovering the capital
11 investment over the twenty-year operational term ofthe agreement as an offset to
12 royalties paid to James River based on contract provisions. The contract costs of
13 energy for the Camas unit are included in the Company's net power costs as
14 purchased power expense, but GRID does not include an offsetting revenue credit
15 for the capital and maintenance cost recovery. This adjustment adds the royalty
16 offset to account 456, other electric revenue, for the Test Period.
17 This adjustment also normalizes the ongoing level of steam revenues
18 related to the Little Mountain plant. Contractually, the steam revenues from Little
19 Mountain are tied to natural gas prices. The Company's net power cost study
20 includes the cost of running the Little Mountain plant but does not include the
21 offsetting steam revenues. This adjustment aligns the steam revenues to the gas
22 prices modeled in GRID.
23 Electric Lake Settlement (page 5.5) - Canyon Fuel Company ("CFC") owns the
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1 Skyline mine located near Electric Lake. Electric Lake is a reservoir owned by the
2 Company that provides water storage for the Huntington generating plant. The
3 two companies have disputed a claim made by PacifiCorp that CFC's mining
4 operations caused the lake to leak water into the Skyline mine, thus making it
5 unavailable for use by the Huntington generating plant. The Company has
6 incurred capital costs and O&M costs to pump water from the breach back into
7 Electric Lake. The two companies negotiated a settlement of the claims made by
8 the Company. The settlement of costs includes reimbursement to the Company for
9 O&M and capital costs associated with the pumping. The value of the settlement
10 wil be amortized over three years. This adjustment reduces rate base for the fixed
11 cost portion of the settlement and includes the first year of amortization for the
12 O&M portion of the settlement. This settlement also includes a new pumping
13 agreement.
14 BP A Exchange (page 5.6) - The Company received a monthly purchase power
15 credit from BP A which was treated as a 100% pass-through customers eligible to
16 participate in the Residential Exchange Program in Oregon, Washington, and
17 Idaho. This adjustment reverses the BP A purchase power expense credit recorded.
18 Tab 6 - Depreciation and Amortization Expense Adjustments
19 Q.Please describe the adjustments included in Tab 6.
20 A.Depreciation and Amortization Expense (page 6.1) - This adjustment enters
21 into the Test Period results depreciation and amortization expense for the major
22 plant added to rate base in adjustment 8.11.
23 Depreciation and Amortization Reserve (page 6.2) - This adjustment enters
Dickman, Di - 19
Rocky Mountain Power
1 into Test Period results depreciation and amortization reserve for the major plant
2 additions added to rate base in adjustment 8.11.
3 Hydro Decommissioning (page 6.3) - Based on the Company's latest
4 depreciation study approved in Case No. PAC-E-07-14, an additional $19.4
5 milion is required for the decommissioning of various hydro facilities. This
6 adjustment includes an annual level of expense in results.
7 New Depreciation Rates (page 6.4) - This adjustment normalizes calendar year
8 2007 depreciation expense to reflect the impact of the new depreciation rates
9 which were effective January 1, 2008 in Case No. PAC-E-07-14.
10 Tab 7 - Tax Adjustments
11 Q.
12 A.
13
14
15
16
17
18
19
20
21
22
23
Please describe the adjustments included in Tab 7.
Interest True Up (page 7.1) - This adjustment details the adjustment to interest
expense required to synchronize the Test Period expense with rate base. This is
done by multiplying normalized net rate base by the Company's weighted cost of
debt in this case.
Property Tax Expense (page 7.2) - Property tax expense for the Test Period was
computed by adjusting accruals through December 31, 2007, for known or
anticipated changes in assessment levels.
Renewable Energy Tax Credit (page 7.3) - The Company is entitled to
recognize a federal income tax credit as a result of placing wind generating plants
in service. The tax credit is based on the generation of the plants and the credit
can be taken for ten years on qualifying property. Under the calculation required
by Internal Revenue Service Code Sec. 45(b )(2), the most current renewable
Dickman, Di - 20
Rocky Mountain Power
1
2
3
4
5
6
7
8
9
10
1l
12
13
14
15
16
17
18
19
20 Q.
21 A.
22
23
electrcity production credit is 2.1 cents per kilowatt hour of the electrcity
produced from wind energy. This adjustment reflects this credit based on the
qualifying production as modeled in GRID.
Schedule M (page 7.4) - The Schedule M items at December 31, 2007 were
updated for known and measurable adjustments through December 31, 2008.
Non-utility items, separate tarff items and other non-recurrng items were
removed from the December 2007 historical perod before updating. For example,
normalizing adjustments were made for items such as pensions, benefits, and S02
emission allowances. Depreciation differences on capital additions were
generated in order to synchronize the Schedule M items with the Test Period. The
Schedule M items were then used to develop deferred income tax expenses and
balances for the Test Period.
Deferred Income Taxes (page 7.5 through page 7.7) - The non-property-related
Schedule M items were used to develop the defered income tax expense. The
property-related deferred income tax expense was generated using the capital
additions and resulting book and tax depreciation. Normalizing adjustments were
added consistent with the Schedule M items as described above. The deferred
income tax expense was then used to develop the deferred tax balance for the Test
Period.
How have current state and federal income tax expenses been calculated?
Current state and federal income tax expenses were calculated by applying the
applicable tax rates to the taxable income calculated in the Report. State income
tax expense was calculated using the state statutory rates applied to the
Dickman, Di - 21
Rocky Mountain Power
1 jurisdictional pre-tax income. The result of accumulating those state tax expense
2 calculations is then allocated among the jurisdictions using the Income Before
3 Tax ("IBT") factor. Federal income tax expense is calculated using the same
4 methodology that the Company uses in preparing its filed income tax returns. The
5 detail supporting this calculation is contained on pages 2.18 through 2.20.
6 Tab 8 - Rate Base Adjustments
7 Q.
8
9 A.
10
1l
12
13
14
15
16
17
18
19
20
21
22
23
Please describe each of the adjustments in Tab 8 made to the historical rate
base balances.
Update Cash Working Capital (page 8.1) - This adjustment supports the
calculation of cash working capital included in rate base based on the normalized
results of operations for the Test Period. Total cash working capital is calculated
by multiplying jurisdictional net lag days by the average daily cost of service. Net
lag days in this case are based on a lead lag study recently prepared by the
Company using calendar year 2007 information. A copy of this study is provided
in the electronic work papers supporting this application. Based on the results of
the 2007 lead lag study, the Company experiences 4.72 net lag days in Idaho
requiring a cash working capital balance of$3.5 milion to be included in rate
base. The net lag days of 4.72 in the 2007 lead lag study represents a reduction
from 5.09 net lag days calculated in the Company's previous lead lag study using
fiscal year 2003 information.
Upper Beaver Hydro Sale (page 8.2) - On September 14, 2007, the Company
sold the Upper Beaver hydro facility to the city of Beaver, Utah. This adjustment
removes the Upper Beaver O&M expenses and the loss on the sale of the
Dickman, Di - 22
Rocky Mountain Power
property. No adjustment to rate base is necessary because the asset was removed
2 from rate base prior to December 31, 2007.
3 American Fork Hydro Removal (page 8.3) - The American Fork hydro electric
4 plant was retired as of September 2007. This adjustment removes the American
5 Fork depreciation and O&M expenses.
6 Powerdale Hydro Decommission (page 8.4) - Powerdale is a hydroelectric
7 generating facility located on the Hood River in Oregon. This facility was
8 scheduled to be decommissioned in 2010; however, in 2006 a flash flood washed
9 out a major section of the flow line. The Company determined that the cost to
10 repair this facility was not economical and determined it was in the ratepayers'
11 best interest to cease operation of the facility. This adjustment reflects the
12 treatment approved by the Commission in Case No. PAC-E-07-04. During 2007,
13 the net book value (including an offset for insurance proceeds) of the assets to be
14 retired was transferred to the unrecovered plant regulatory asset. In addition,
15 future decommissioning costs wil be deferred as they are spent and amortized
16 over ten years, beginning in the subsequent year after they are spent.
17 Goose Creek Transmission (page 8.5) - On April 1, 2008, the Company sold its
18 undivided interest in 13.85 miles of transmission line, running from the
19 Company's Goose Creek switching station and extending north to the Decker 230
20 kV substation near Decker, Montana. In addition to the radial transmission line,
21 the assets sold included structures and miscellaneous support equipment,
22 easements and rights-of-way associated with the transmission line. The sale of the
23 transmission line resulted in the Goose Creek switching station no longer being
Dickman, Di - 23
Rocky Mountain Power
1 needed or useful to the Company. In the summer of2008, the Company plans to
2 remove the Goose Creek switching station including all equipment, strctures,
3 slabs and other above ground facilities and level the site. After removal of the
4 switching station, the Company wil build a short segment of 230 kV transmission
5 line to ensure continued operation of its Sheridan to Yellowtail 230 kV
6 transmission line. This adjustment amortizes the net gain associated with the sale
7 over three years, reduces rate base by the net book value of the assets sold and
8 adds the new Yellowtail line into rate base. The Company notified the Idaho
9 Commission of the planed sale of this utilty transmission plant facility in a letter
IOdated August 21, 2007.
11 Environmental Settlement (PERCO) (page 8.6) - In 1996, the Company
12 received an insurance settement of$33 milion for environmental clean-up
13 projects. These funds were transferred to a subsidiar called PacifiCorp
14 Environmental Remediation Company ("PERCO"). This fund balance is
15 amortized or reduced as PERCO expends dollars on clean-up costs. PERCO
16 received an additional $5 milion of insurance proceeds plus associated liabilities
17 from Rocky Mountain Power in 1998. This adjustment includes the unspent
18 insurance proceeds in results of operations as a reduction to rate base.
19 Customer Advances for Construction (page 8.7) - Customer advances were
20 recorded in December 2007 using unadjusted data to a corporate cost center
21 location rather than state-specific locations. This adjustment corrects the
22 allocation of customer advances.
23 Trapper Mine Rate Base (page 8.8) - The Company owns a 21.4 percent share
Dickman, Di - 24
Rocky Mountain Power
1 of the Trapper Mine, which provides coal to the Craig generating plant. This
2 investment is accounted for on the Company's books in account 123.1, investment
3 in subsidiary company, which is not included as a rate base account. The
4 normalized coal cost from Trapper Mine in net power costs includes O&M costs
5 but does not include a return on investment. This adjustment adds the Company's
6 portion of the Trapper Mine net plant investment to rate base in order for the
7 Company to earn a return on its investment.
8 Jim Bridger Mine Rate Base (page 8.9) - The Company owns a two-thirds
9 interest in the Bridger Coal Company, which supplies coal to the Jim Bridger
10 generating plant. The Company's investment in Bridger Coal Company is
11 recorded on the books of Pacific Minerals, Inc. Because of this ownership
12 arrangement, the coal mine investment is not included in electric plant in servce.
13 This adjustment is necessary to properly reflect the Bridger Coal Company
14 investment in rate base in order for the Company to earn a return on its
15 investment. The normalized coal costs for Bridger Coal Company in net power
16 costs include the O&M costs of the mine but provide no return on investment.
17 Miscellaneous Rate Base (page 8.10) - In this adjustment cash is removed from
18 rate base to avoid earning return on rate base on the balance. Also, an anticipated
19 increase in fuel stock is added due to increases in the cost of coal and the number
20 of tons stored at each site.
21 Pro Forma Major Plant Additions (page 8.11) - To reasonably represent the
22 cost of system infrastrcture required to serve our customers, the Company has
23 identified capital projects that wil be completed by December 31, 2008.
Dickman, Di - 25
Rocky Mountain Power
1 Company business units identified capital projects with expenditures over $5
2 milion that wil be used and useful by this date. Additions by functional category
3 are summarized on separate sheets, indicating the in-service date and amount by
4 project. The associated depreciation expense and accumulated reserve impacts are
5 accounted for in adjustment 6.1 and 6.2.
6 FERC 105 (PHFU) (page 8.12) - This adjustment removes all plant held for
7 future use ("PHFU") assets from FERC account 105. The Company's is making
8 this adjustment in compliance with Title 16 of Public Utility Regulation, chapter
9 5, "Powers and Duties of Public Utilities Commission" section 61-502A.
10 Chehalis Generating Plant
11 Q.The Company recently announced it is acquiring the Chehalis generating
12 plant located in Washington. Is this new resource included in this rate case?
13 A.Yes. This case assumes that the Company's purchase of the Chehalis plant wil
14 take place as scheduled and preliminar estimates of the rate base, O&M and
15 taxes associated with the plant are included at the anualized level similar to other
16 Company-owned resources. Due to confidentiality requirements the amounts
17 related to the Chehalis plant included in Exhibit No. 12 are combined with other
18 items. Confidential Exhibit No. 13 indicates the pages in Exhibit No. 12 that
19 include amounts related to Chehalis, and gives a detailed breakout of the
20 specifics. In Case No. PAC-E-08-02 the Company requested and was granted
21 deferred accounting treatment of an exclusivity payment made to the plant's
22 current owners in the event the purchase transaction fell through. This treatment
23 wil not be necessary as the transaction closed on September 15, 2008, and the
Dickman, Di - 26
Rocky Mountain Power
1
2 Q.
3 A.
payment is included in the capitalized cost of the plant in this case.
Does this conclude your direct testimony?
Yes.
Dickman, Di - 27
Rocky Mountain Power
.SfP l 9 Al1 10: 52
IDAHO PUBLiC
UTILITIES COMMISSION
Case No. PAC-E-08-07
Exhibit No. 12
Witness: Brian S. Dickman
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Direct Testimony of Brian S. Dickman
Revenue Requirement
September 2008
THIS EXHIBIT IS VOLUMINOUS
AND IS PROVIDED UNDER
SEPARATE COVER
2881 SEP 19 AM II: O&ase No. PAC-E-08-07
UBLt~ Exhibit No. 12lDAHO P . .' .' .
UTILITIES COMMk siò¥tness. Bnan S. Dickman
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Direct Testimony of Brian S. Dickman
Revenue Requirement
September 2008
i
r'."."""
tn ",
Rocy Mountain Power
IDAHO
Result of Oprations - REVISED PROTOCOL
12 Months Ende DECEMBER 2007
Pa 1.0
(1) DECEMBER 2007 RolleIn Revenue Requirement
(2) Rate Mittin Cap
(3) cape Revise Prtocl Revenue Reqirent
(4) Noali Gene Busiess Revenues
(5) Cappe Revised Protocol Price Chang
213,892,110 Page 1.4
101.67%
217,46.109
201,179,561 Pag 1.4
16.284,547
Revi Prol
(6) Filed Revis Pro Reve Reqiren
(7) Nomialized Generl Business Revenues
(8) Revis Protocl Pnc Chang
(9) Capp Revised Protol Price Change
(10: Red to Revis Pl'toco Revnu Reqent
220,613,392 Page 1.1
201,179.561 Page 1.1
19,433,831 Page 1.1
16,284,547 Fro Abo
(3,149,284)
Rocky Mountain Power Pag 1.1
IDAHO
Reslt of Opetions. REVISED PROTOCOL
12 Months Ended DECEMBER 2007
(1)(2)(3)Tot Res wiResPr Ch Pr Ch
1 Opti Reves:2 Ge Bu R_201.179.561 19.433.831 22.613.3923 Inta4 Sp sale 135.64.975 0I Op Revue 8,651,785
6 Tot Op Re 345,476,324
7
8 Opti Ex..:9 St Pro 56.616.9410 Nuc Pr11 Hy Pr 2.142.79
12 0I "- Su 175,19,2613 Traio 10.2.38
14 Ditr 10.721.16215 Cus Acc 4.33,756 32.99 4.36,749
16 CustQ 5e & In 1,815.521
17 Sa18 Ad & Ge 10.162,64
19
20 Tot O&M Ex..271,383
2122 De 22.85.18723 Am 3.21e.68
24 Taxes 0I Th In 5.111.661 5.111.661
25 In Taxes. Fed 1.410.671 8,48.015 7.8.68
26 In Taxes. Slae 45.921 88.79 1.33.719
27 In Taxes. De Net 5,57132
26 in Tax Ci Ad.(218.44)29 MI Rev & ex /241,05D
30
31 Tot Op Expe:30.510.973 7.395,80 318,90.m
32
33 Op Rev For Re:359635 1203927 4800379
34
35 Ra Ba: 36 El PIIn 5e 1.011.517,272
37 PI Hel fo Fut Us 038 Mis De De 4.037.561
39 El PI Ac Ad 4.34.96
40 Nu Fue41 Pr 2,29.23
42 Fue Sto 7.48U91
43 Ma & SUpp 9.03._44 Wor Ca 3.8.4845 Wei lo 5.59.437
48 MI Ra Ba 361.126
47
48 Tol El Pl 1.04.48.48 1.04.48462
4950 Ra Ba De:51 Ac: Pi For De (370.88.49)52 Ac Pi Fo Am (21.62.63)
53 Ac De In Tax (82.46)
54 im ITC (115.06)
56 Cu MY For Ca (499.56)56 Cu Sere De .57 MI Ra Ba De /7,118,00)
56
59 Tot Ra Ba De (48.06.30)(48.06.30)
60
61 Tot Rae Ba 5649156 5640156
62
63 Ret on Rae Ba 8.361%8.49
6465 Ret on Eq 8.52 10.75
66
87 TAX CAUlTIO68 Op Rev 43190.631 19.40.8 82591.47169 0I De70 imi (AF)
71 InI 17.247.20 17,247.2072 Sc'M" Ad 39.55.03 39.55.0373 Sc'M" De 56,933,221 55933,221
74 In Be Tax 9.56.2 19.400,84 28.96.0n
75
78 Sta In Taxes 45,921 68,79 1,33,719
n Taxbl In 9199317 1852041 2762 358
78
79 Fed In Taxes + 0I 1419W1 6.482015 78968
Re. Pa 2.
Roç Montin Power
IDAHO
Results of Opraons. REVISED PROTOCOL
12 Mont Ended DECEMBER 2007
".1.
Rocy Mountin Power
IDAHO
Results of Operations - REVISED PROTOCOL
12 Months Ended DECEMBER 2007
Pag 1.3
Operatin Revenue 100.00%
Operating Deducions
Uncollectble Accunts
Taxes Ot - Franchise Tax
Taxes Ot - Revenue Tax
Taxes Otr - Resorce Supplier
Taxes Otr - Gross Recpts
0.170% Se Note (1) be
0.00%
0.00%
0.00%
0.00%
Sub-Total 99.830%
State Ince Tax (g 4.54%4.532%
SubTotal 95.29%
Fedral Incme Tax (g 35.00%33.354%
Net Oprating Income 61.94%
(1) Uncectible Accnts =341.528
201.179.561
Pg 2.12, Situs frm Accunt 904
Pg 2.2, General Business Revenues
1 0p Reven:2 Ge Bu Rev3 In4 Sp Sa5 Ot Opg Rev8 Tot () Rev
78 0p Ex9 Ste Pi10 Nu Pi11 Hy Pi12 Ot Po Su13T~14 Di15 Cu Aç18 Cu 5e & In17 Sa18 Ad & Ge
1920 TotO&MEx
2122 De23 Am
24 Taxes Ot Th In25 In Taxes. Fed
28 Inc T_. Sla
27 In T_. De Ne
28 Ines Tax Cn Ad. .29 Mis Rev & Ex
3031 Tot Op El:
3233 () Re For Re
34
35 Rat Ba:36 EI Pl1n Se37 Pl He fo Fu Us38 Mi De De
39 EJ PI Ac Ad40 Nu Fu41 Pr
42 Fue Sl43 Ma & Supp44 Wll C845 Weø i.46 Mi Ra Ba
47
46 Tot El Pl
4950 Ra Bæ De:51 Aci Pr For De52 Ac Pr For Am
53 Ac De In Tax54 UIl ITC55 Cuto.Ad For Co56 Cu 5e De57 Mi Ra Ba De
5659 Tot Ra Ba De
6061 Tot Ra Ba:
6263 Ret OI Ra Ba
6465 Rel OI Eq
66ff TAXCACUli"66 0p Re69 Ot De70 Inte (AF)71 In72 Sc V Ad73 Sd oM" De
74 In 8e Tax
75
76 Sta In Taxes77 Tax In
7879 Fedln T_ + Ol
Rocky Mountain Powr
IDAHO
Reslt of Opetions. ROLLED-IN
12 Months Endd DECEMBER 2007
(1)TotReslt
201.179,561
13584.978
8,65,027
345,476.56
56.95.52
2.142.7916.96.6510.23.38
10.721,162
4.33.756
1.815,51
10,175.05
26.341,6
22.876.35
3,21.201
5.118,1633.6965
878.09
5,56.379
(218.44)
(241.041)
30.2.194
10217372
1.013.30.211
o
4.038.07
4.34.96
2.29251
7.521.88
9.049.8703.752,2
5.5.437
381,128
1.05,279.09
(371.57.28)
(21.642.57)
(82,30.310)
(158338)
(499.65)
(7,119,125)
(48827.218)
5645'878
7.100
7.99
50.160.067
17.2.0439.5,61
55,947,330
16,524.50
878,09
1564414
36965
(2)
Pr CI
12.712,59
21.561
4,240.179
576.170
4.837.li
7874619
12._,9
12.6l.96
576,170
12.114 79
4249 179
Pag 1.
(3)Res wIPr Ch
213.89.110
4.35.33
5.118,1637,9383
1.454.28
310.097.125
4899199
1.05,279.09
(46.87,218)
56451876
8.490
10.75
62.651.025
17.2.04
39.59,61
55.947,330
29,215.4n
1,45.26
2776' 21
Ref. Pa 9.2
79383
P,,,'.5
ROCKY MOUNTAIN POWERSloflc.iAc AdjuØd & Nc R..ii of Oper.i . Rll ProtolTw.. Mo Ende oe.. 2007
(1)(21 (3)(4)(5)(6)(7)
UrujuØd Typ 1 TNI AdlusØd Typ 2 TNI Annu.ilu TYP'3 TNlIb
R..ui Ac_ta Aduel R..ui Ac_ta AcHIit1l ~Res
1 0p R__:2 ~.i Bun.. Rtu..184.199 5,16,135 181.615,96 (8.815)18l&07.152 1'.574O 20..179.'
3 Intt
4 Spi.ihles 51,2.667 51._817 51,2667 8411 13584.178
5 0l Opnig Rt..7.21;50 øi:=)i;77I;7l 11 &.825,1..55 "'&61.785
6 TNI 0p R_247.721,52 17.7M3 l!47.32424.51000 24768426
7
8 Opnig Eii:I Sl Prucon 545517 137.n1)54515.21._54,24 2,,674 5&81l.
10 Nu Pr11 Hydr Pron 2,078,03 51,02 2,12904 3,141 2,1321l5 1o.l7 2.147t
12 Oler P_er SU 78.7299 7..04 8lm.032 7.72 8l7&O ..73 1'711.6.
13 T..iiui 9.33318 18004)9,,21 3,58 9.3385 903,52 10.23
14 Dllrbuon 10.8429 137.114)10.60180 20.681 10.82861 9430 18.72.18
15 Cus_ Acounl 4,23,42 8,l8 4..38 14,62 4,2l,0 337.4,3768
16 C.. Se 3,86.66 (205170)1.6096 1.50 1.810.463 5,_''''5,
17 SI,. Admln & Gen 93567 1.154 18,81."16.40 10.8l.96 l!'4l 10.1!U
xx
11 Tot O& Exp"173,003,_8,_.412 171..32011 89.3 188021.:l77 91,3 271.34
xx20 Deon 23811._(33207)23m.32 t4 2472155 11.874,"')2285.187
21 Ain 3,061,879 IU.82 2,ll057 45 2,m.511 22.55 3,1t,
22 T_ Oler Than in_4,583,690 4,583,810 4,583,610 60.971 5,111.681
23i-T.....F..4,75226 (1,81.95 2,87,310 (6"'831)2,171,4 (7.B 1,4'0.671
24 i- Tun. Sl 706805 (167.815)53tt 145-)4tlI 138G7)45921
251_T.....OtfNe 3.014,869 3,014,86':s14,86 2,5,57132
25 i-tm T.. Cndll Adj.1707.091)1707.09')1707"")..84 (218,44)
27 MI Rt & Exse 1734528l 52751 1205J 1205J pa!l fW7l
xx
20 TNI Ope i!:211.413,072 5,3030 2180717._30.43 217.017.812 t2181 301t",73
2l
30 0p Re For"-31.09.1I8 (129681)30.967.047 (887)30.703,240 5,2112 3$5,
31
32 ReB_:33 EI Plant In Se t4to63 '0.212,401 151.1..33 l51.1H.8 8O 1,01..7,2
34 PI Ht fo Fut Us 882,985 (805)0 0 0
35 MI Def Deb 3,99 (21 3,1Q 3,1Q 74,1.4M,S1
3t Elec PI Ac Ac 4,3496 4,34'"4,34 4,'"
37NuF..38 Preeyta 2,2,23 2,2l z.
38 Fue Stk 6.312,616 &.312,ti16 &.312,1ti 1,1".071 7,11,6
40 M.. & Suli 1,033698 9.033698 1.033ti98 9.03
41 Wo Cepltl 3,8683 (1,2915)2,83715 (8..2,35 1.178,132 3,
42 Wuer L_..597 5,5,..43
43 MI Re B_381,28 311,28 381,28 311,28
xx
44 TNI eic Pl:977,5,579 8,137.83 981 (1.)98ti ,8 till14 1...AU
45
46 Re ... Deuct:
47 Accum Pro For OepNC (3t.2954)..981 (384t)(38,41 (1...03)(3)
48 Acm Pro For Am (21.58618)121.586181 (21,518)(38012)12.ti)
49 Ac Dtf Incom T..(121""85 1821""85 (8 tti1 (8ti11)(84t)
50 lI IYC (52151 1525)(525)18214 (115,06)
51 C_ Adv For Cont (131.031)(38.ti)(4l65)(..651 (4ti
52 C.. Stce Dt
53 MI Re .. Oedct 13,3!26)l375t)(!!!17 (US.,7)(153 I! '1!
54
55 Totl Re B_ De (478.5352)(3,9829)(..51&.82)(_51'.1)(2,48 (48..3O)
5t
57 Tot Re"": .Wpsp 413.."'31 (f3!595,'1'02 ".'D ...155
58
59 Rt on Re ..6.07%ti30 U7f Uti1%
xx
ti Rt on Equi 6.2%"0.152 ...."0.103%5..."8.
61
ti TAX CALCULATIO83 Opng Renu.38"3,772 (2, 171.ti 38...,24 (1,O 35 7'-_431901
84 0l Dedon
ti Int (AFUD)
ti Inte,..t 13,2,35 1.51&.721 '5,077 (2 ,....82 1.839 t7.24,210
67 Sc"M" Addion 4'.817i51 41.817.151 41.817.151 (2 113)3903
ti SCed. "M" De 52583,871 52583,871 52503,871 3,4,3 5593322t
69 1_ B.fo T..14,28.697 13,698370).0,5,37 (9l.77 9,58.55 (27)9,238
7071 Sl i- T_706~80 :.81'538~99 /45-~4!60 (38.679)9im72 TlIlnom 13.W;'92 19:04(33 Ilv,383i 9,94955 4,8
73
1352,555
74 F.. i- T.... + Ot 4,752,252 (1,881.95)2,87.310 (8901)2,17948 (7''')1.410.671
(1) Typ 1 td_tain nolu for ou of perod tdju_ en un"l_ tl ocur dur th - ped.
(2) Typ 2l1ua_ta annutze ch.. tht oc durng th tet pe.
(3) Typ 3 ~ta ., known en _urtb it tl wlU ocur In . fu tee pe.
IOSUMRY OF ADSTNTS TOTAL Pag 1.
Ne Po CORe Adtm O& Adtm Ad Deeeon &Tax Adimls Ms Ra Bae
Tot AdIS (Tab 3) (Tab 4) (TabS)Amon (Tab 6)(TabT)Ac (Tab 6)
1 0p R_:2G-_R_18,979.72 16.979.723 -.en4 Sp5a 8411 84.3115 0l0p ~1.30285 1.)48.08 135410 44167
6 Tol 0p ~10296.3 18.026,36 135410 84.80478
7
8 0p --9S_~2.06 5893 2.0010 Nu~11 Hy PnØ 64.58 74.2 (9.4$7)
12 0l ~ Su 98.63 7.6085 "98.97l)T..90.0 154.8 746.29
14 Dilr 77.88 (3672)114.515 Cu Ac 57.3 57.3
18 Cutoer S- & ii (2.05138 (2.0!.139)
17 SI18 Ad I ~-63078 877.578 (241.50
19 Tol O& ei 9834.2 (3672)6.88015 91.00.416 (9.41)20 De (9&1.02)(55)(92.58)(337)
21 Am 157.189 (7.59)(10.5)76,8 9855
22 T_ 0l Th In 60.971 60.97123_T_:F-.(3.1.5)5.78.46 (2.17,:191 (2.34.12)28.24 (4.9936 (6.*')
24 Sl (251.18)785741 (29)(30 3862 (475.92)(ea)
25 De_ T_2.58 UÐ.28
26 -. Tax CiAf.48647 -"7'Z MI_ie-49472 7!l103 (2)(36.92)
26 Tol 0p__98.09.90 7;l.57 4.179.00 68.951,5 (52.88)(1.06.411)12.05
29
30 0p Re Fli Re 4.842 10.7385 (4.0459)(4.141J.l85)52'-1.06.411 112.(5)
31
32 Raii33 El PI In Se 7D6".63 (24.11l 7D.8
34 PI He fo F'- \J (80.9 (ae_
3S MI De De 45 (2U 1429 (68181)
38 I! Pl Ac Af37 Nu FI38~39 FI Sl 1.169075 !l 1.'711
40 Mi i Si41 Wo C8 (83149 (Ð.l49
42 we I.
43 MI Ra ii
44 Tci El_70.9588 (26.86)(9.58)7D991l.33
41
48 De47 _ _Feoe (1.87.94)2.11 (1.lI84)4008
48 _ _FoAm (382)38 (78).._De_Tax (6811)(l811)
50 ui lT (62.11)(62.8
51 Cu_MlFoCo ("62 (386252C_S-~5: ~ De (3.80.739)(2.541)(187.8 (93.541)
54
55 Tot De (6.77)(2.6.51)(146,6)(1.07.014)(743.45)(1.6808)
56
57 Tot Ra ii &4.14.104 (2.ea.541)(286)(15826)(1.707.014)(74345)69732.249
58
5Ø
60 Is RO Ii D.4.3 .1.60,..1.~4 ~o.73 .1.lI
61
62Ð
84 TAX CACUTI
8511 Op _4.32 17.3l.0 (8.1&.774)(8,7I)_75 (60.171)(19.42
87 Ol l)11 _(AF)69_3..8 3..8
70 $d"M Ad (2.26113)(2.113)
72 $d "M' De ).4235 3.42
73 1_1L Tax (4.7245)17.3l.06 (&.1&774)(6.6178)1l757 (9.85)(19,4'Z)
7476 St 1_ T_(251.8)78741 (2986 (30)38624 (475.92)(ea)771"-_(4.46575)1&.521.22 (6.912)(&.38)112.33 (9.179.3)(18.46)
7879F-"_T_(3.341.59)5.78246 (2.17.319)(2,23.123)28.2 (4.99.367)(6,91)
2
Rocky Mountain Powr
RESULTS OF OPERATIONS
Pag 2.1
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAH
DECEMBER 2007
FILE:
PREPARED BY:
DATE:
TIME:
JAM 10 De7 GRCRevue Reqem De9100
1:25:05 PM
TYPE OF RATE BASE:
ALLOCTION MET:
Yea-End
REVISED PROTOCOl
FERC JURISDITION:See Jurion
80R 12CP:12 Cota Pea
DEMANO%
ENERGY %
75% Dean
25% Eney
TAX INFORMATION
TAX RATE ASSUMPTIONS:
FEDERAL RATE
STATE EFFECTIVE RATE
TAX GROSS UP FACTOR
FEOERASTATE COMBINED RATE
TAX RATE
35.00%
4.54%
1.614
37.951%
CAPITAL STRUCURE INFORMATION
CAPAL
STTURE
EMBEDDED~WEIGHTED~
DEBT
PREFERRED
COMMON
49.20
0.40
50.40
100.00%
6.20%
5.41%
10.75%
3.0s1e0.02
5.418%
8.490
OTHER INFORMATION
REVISED PROTOCOL Page 2.2
Year-End
RESULTS OF OPERATIONS SUMMARY
UNADJUSTED RESULTS IDAHO
Descripton of Account Summary:Ref TOTAL OTHER IDAHO ADJUSTMENTS ADTOTAL
1 Oprang Revenues
2 Geral Busi Revenues 2.3 3.228.941.107 3,44.741.273 184,199,83 16.979.728 201.179,51
3 Interdeprtentl 2.3 0 0 0 0 0
4 Specia saes 2.3 85.86.831 80.576.164 51.288.667 84.3.311 135,64.978
5 Ot Operang Revenue 2.4 156.475.422 149,45,922 7.021.500 1,630.285 8.651.785
6 Total Optig Revenues 2.4 4.242.281.360 3,999.771,360 242.510.000 102,966.324 34.476.324
7
8 Opeting Expese:
9 Steam Pron 2.5 854.98,104 80,429.788 54,55.317 2,06,82 56.616.949
10 Nucar Proucio 2.6 0 0 0 0 0
11 Hy Prucon 2.7 34.359.36 32,281,33 2.078.033 64.759 2.142.792
12 Oter Powr Supp 2.9 1.199.378,442 1.120.65,452 78.724,99 96,59.636 175,319,26
13 Transmissi 2.10 154.194.872 144.85.554 9.33,318 901,06 10.26.38
14 Distrbutn 2.12 221,34,872 210.697.578 10.64,24 77,88 10.721.162
15 Custer Acunting 2.12 95,457.766 91.184.36 4.273,420 57.33 4,.758
16 Cuser Servic & Infor 2.13 46,96.452 43.100,792 3,86.66 (2,053,139)1.815.521
17 Sales 2.13 0 0 0 0 0
18 Adminti & Gene 2.14 180.356,471 170.82,90 9.526,567 63.076 10,162.84
19
20 Tot 0 & M Exses 2.14 2.787.04.388 2.614.03.769 173.003,599 98,32,2 271.3.834
21
22 Deti 2.16 417.781,814 393,970,225 23.811.589 (91.402)22.85.187
23 Amort 2.17 64.157,451 61.09,572 3,061.879 157.189 3,219.068
24 Taxes Ot Than Incme 2.17 101.472,747 96.96.05 4.503.90 601.971 5.111.661
25 Incme Taxes. Fedl 2.20 150,961,776 146.2.514 4,752.282 (3,31,591 )1.410.671
26 Incme Tax. State 2.20 23,501.832 22,795.027 706,805 (251.88)45.921
27 Incme Tax . Def Net 2.19 78,94.590 75,93,721 3.014,86 2.58,2 5.578.132
28 Investent Tax Creit Ad.2.17 (5,85,86)(5,147.769)(707.091)488,647 (218.45)
29 Mise Revee & Exnse 2.4 (11.34.723)(10.609,194)(734.528)493.472 (241.051)
30
31 Tota Op Exnse 2.20 3,60,682.99 3.395,269.92 211.413.072 98097.91 30.51Ð.73
32
33 Opra Revenu fo Re 83.596.36 60,501,43 31.09.928 4.86.423 35.965.52
34
35 Rat Ba:
36 Elec Pl In Serve 2.30 16.347.947.99 15.407.04.359 94.90.633 70.611.839 1.011.511.212
37 Plt He fo Fut Us 2.31 13.697,167 12.894.162 802.965 (802.98)0
38 Mi Defe De 2.33 133.178.754 129,166.5 3.992.248 45,3 4,037,551
39 Ele Pl Ac Adj 2.31 71.825.613 67.481.64 4.3.96 0 4,34,96
40 Nuclear Fuel 2.31 0 0 0 0 0
41 Prepaent 2.32 39.29.95 37,002,726 2.29,233 0 2,29.233
42 Fuel Sto 2.32 96.239.038 89.926.422 6.312.616 1,169.075 7.481.691
43 Materil & Suplis 2.32 149.777.022 140.743.324 9,033.69 0 9.03,69
44 Workin Ca 2.33 73.96.040 70.09,40 3.86.83 (63.149)3..484
45 Weathrin Loans 2.31 10.89,479 5.29.042 5,592.437 0 5.592.437
46 MlUaeo Rate Base 2.34 5.149.166 4.768.058 381.128 0 381.128
47
48 Total Ele Plant 16.941,967,249 15.96.43.670 977.528.79 70.959,884 1.048.48.46
49
50 Rate Base Døns:
51 Accum PIv For Depr 2.38 (6.184.56.183)(5.615.271,641)(389.292.542)(1.581.949)(370.88.49)
52 Accum Prav For Amort 2.39 (402.210.25)(380.624.838)(21.58.618)(36.012)(21,23.63 )
53 Accum Def Income Tax 2.35 (1.32.49.178)(1.247.325,321 )(82,164.857)(68.611)(82,45.468)
54 Unamor ITC 2.35 (10.54.126)(10.490.911)(52,215)(62,8)(115,06)
55 Custo Ad for Ca 2.34 (17.48.789)(17,35.757)(131.031)(368,25)(49,65)
56 Custoer Seice Deposit 2.34 0 0 0 0 0
57 Mi Rate Base Dectons 2.34 (59.165,85)(55.857,419)(3.308.26)(3.807.738)(1116.03)
58
59 Total Rate Base Dects (8.003.45,216)(7.526.924.68)(476.53.526)(6.54.77)(48,08.30)
60
61 Tota Rate Base 8.938.508.033 8.437.513.982 50.99,050 64.414.104 565.40.155
62
63 Retm on Rate Base 7.111%6.207%6.31%
64
65 Retrn on Equi 8.013%6.220%6.526%
68 Net Powr Costs 94.86,037 62,976.362 66,08.32
67 100 Bais Points in IËquity
68 Reve Reqirment Impa 72,60.04 4.08,381 4.592.592
69 Rae Base Decrease (591,613.056)(37.624,690)(41.510.215)
REVISED PRTOCOL Pag 2.3
Yea-lnd
I'RC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRI'FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTENT ADJTOTAL
70 Saes to Ulmate Custom
71 44 Residtial Sa
72 0 5 1.26.790.93 1.214.26.337 49.527.597 8.00,554 57.534.151
73
74 81 1.263,790.93 1.214,263.337 49.527.597 8.00.55 57.53.151
75
76 442 Coer & In Sas
77 0 5 1.92.738.24 1,794.30.878 134.429,145 8,777.711 143,2,85
78 P 5E
79 PT 5G
80
81
82 81 1.928,738.024 1.794.30.878 134,429.145 8.777.711 143.206.856
53
84 44 Pub Stt & Hi Ught
85 0 5 18.902.69 18.659.599 243.091 195.46 43,5
86 0 50
87 81 18.902.690 18.659.599 243.091 195.463 438.554
88
89 44 Ot Sa to Pu Auth
90 0 5 17.50.459 17.509,45
91
92 81 17.50,459 17.509.459
93
94 44 Inlepa
95 DP 5
96 GP 50
97 81
96
99 Tol Sale to Ultimae Cusmers 81 3.2,941.107 3,044741,273 184,199,833 16.979,728 201,179,561
100
101
102
103 447 Sa fo Real NPC
104 WSF 5 7.816,288 7.816.288
105 7.816,288 7,816.288
108
107 447N Sa fo ReC
108 W5F SG 88.870.22 810.88.375 52.185.855 83.45.124 135.644.978
109 W5F 5E (13.21.88)(12.724.49)(897,187)897.187
110 WSF 5G .
111 84.248.54 797.959.876 51,28.867 84.35,311 135.644.78
112
113 Tot Sats fo Resle 81 85,86.831 805.576,164 51.288.867 84.35.311 135.644.978
114
115 44 PI' fo Rate Ref
116 W5F 5 3 3
117 WSF SG
118
119
120 81 3 3
121
122 Totl Sa frm Eleit B1 4,085,805,94 3,850,317,44 235,48,50 101,336,039 33,824.539
123 45 Foif oi & Ineret
124 CU5T 5 6.784.670 6,416.032 368.639 36.63
125 CU SO
128 B1 6,784.670 8.416.032 368.39 36.639
127
128 451 MI Ele Renu
129 CUST 5 7.20.337 7.062.014 142.323 142.323
130 GP 5G
131 GP 50 10.908 10.281 628 628
132 81 7.215.245 7.072.295 142.951 142.951
133
134 45 Wat Sa
135 P 5G 107.48 100.979 6,00 6,00
136 81 107.48 100.979 6,00 6.500
137
138 45 Re of Ele Pro
139 OPW 5 12.80.49 12.473.818 335,675 33.675
140 T 5G 5.274.077 4.955,104 318.973 318.973
141 GP 50 677,192 63,216 38.976 135,410 174.386
142 81 18.760.759 18,067,136 693.623 135.410 829.033
143
144
REVSED PROTOCOL Pag 2.4
Year-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADJTOTAL
145
146 456 Oter Elelri Revenue
147 DM5C 5 28.947.69 28.946.013 1.679 1.679
148 CU5T CN
149 OTHSE 5E 15.573.968 14.548.195 1.025,774 61.176 1,08.949
150 OTH50 50 244.061 230.014 14.047 14.047
151 OTH5GR 5G 78.841.54 74,073.25 4.768.288 1.433,699 6.201,987
152
153
154 81 123,607.26 117.797,478 5.80,787 1,494,875 7.304.662
155
156 Totl Other Electric Revenues B1 156,475.419 149.453,920 7,021.500 1,630.285 8.651.785
157
158 Total Electric Opeting Revenues B1 4.242.281.360 3.99.771,360 242.510.000 102,96.324 34476.324
159
160 5ummary of Revenues by Factor
161 5 3,29.30358 3,107.255.43 185,048,148 16.979.728 202.027.876
162 CN
163 5E 1,952.282 1,82.696 128.586 958.36 1.08.949
164 50 932,162 878.511 53.651 135,410 189.061
165 5G 947,093.33 889.813.715 57.279.615 84.892.823 142 172.43
166 DGP
167
168 Tota Ele Optig Revenues 4.242.281,360 3,999.77.360 242.510.000 102.966.324 34,476.324
169 MiseHaneous Revenues
170 41160 Gain on 5ale of Utility Plant. CR
171 DPW 5
172 T 5G
173 G 50
174 T 5G
175 P 5G
176 81
177
178 41170 Loss on Sale of Ut Plant
179 OPW 5
180 T 5G
181 81
182
183 4118 Ga fim Emission AHoancs
184 P 5
185 P 5E
f4.663.498)
(13.697.692)(965.06)758.103 (207.703)
186 81 14.663.498)(13,697,692)(96.806)758.103 (207.703)
187
188 41181 Gan fr Diposin of NOX Creit
189 P 5E
190 81
191
192 4194 Impact Hosing Interest Income
193 P 5G
194 81
195
196 421 (Gain) I Los on 5a1 of UtHty Plant
197 DPW 5 (706.221)(706.221)
198 T 5G
199 T SG
200 Pro CN
201 PT 50 4.175.984 3.935.63 240,349 (228.23)12,110
202 P 5G (149.988)(140.917)(9.071)(36.392)(45,463)
203 81 3.319.775 3.088,498 231.277 (264.631)(33.353)
204
205 Totl Miscellaneous Revenues (11.343.723)(10.609.194)(734.528)493,472 (241,057)
206 Milaneous Exnses
207 4311 Interest on Customer Deposits
208 CU5T 5
209 81
210 Total Miscellaneous Expenses
211
212 Net Mise Revenue and Expense B1 (11.34.723)(10,609,194)(734.528)49.472 (241.057)
213
REVSED PROTOCOL Page 2.5
Vearnd
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
214 50 Optin Supervision & Engineerig
215 P SG 20.195,720 18,974.29 1.221.425 12.303 1.23.728
216 P SSGCH 1.310.396 1.23.295 75.101 75.101
217 82 21,50.117 20.209.591 1.29.526 12.303 1.30,829
218
219 501 Fuel Reltedn NPC
22 P SE 12.819.982 11.975,599 84.383 610 84.99
221 P SE
222 P SE
22 P SSECT
224 P SSECH 1,782.99 1.655.649 107.351 107.351
225 52 14.582,982 13.631.247 951.734 610 952.344
226
227 501NPC Fue RelatPC
228 P SE 516,191,53 482,192.770 33,99.787 1.759.50 35.758.76
22 P SE
230 P SE
231 P SSECT
23 P SSECH 50,403.877 47.334.730 3.069.147 332.381 3.401.527
233 82 56.595.413 529.527.500 37.067.913 2.091.890 39.159.803
23
235 Tot Fue Rela 581,178.395 54.158.747 38.019.64 2,092,500 40.112.147
238
237 50 Ste Exse
238 P SG 31,714,301 29.79.240 1.918.061 13.90 1,931,96
239 P SSGCH 2,05.090 1.93.423 117.666 117.666
240 B2 33,767.391 31.731.664 2.035.727 13,908 2,049.636
241
242 50 Stea From Ot Sorc-NPC
243 P SE
244 52
245
246 503NPC Stea Fro Ot SouC
247 P SE 4.845,079 4.525.96 319.119 (85,191)233.92
248 52 4.845.079 4.525.96 319.119 (85.191)233.929
24925 50 Ele Ex
251 P SG 2.687.282 2.524.757 162.525 1,261 163.787
252 P SSCH 1,320.614 1.244.928 75.687 75.687
253 82 4.007.896 3.769.684 238.212 1.261 239.473
25
255 50 MI St Ex
256 P SG 40,241.240 37.807.474 2.43.765 (2.577 2.431.188
257 P SE
258 P SSGCH 1.60.35 1.511,459 91.891 (15)91.876
25 52 41.84.590 39,318,934 2.525.656 (2.592)2.523.64
260
261 507 Ren
262 P SG 743.038 698.099 44.938 44.938
263 P SSGCH 116,165 109.508 6,658 6.658
26 B2 859.203 807.607 51.596 51.596
26526 510 Main Suison & Enerig
267 P SG 4,413.141 4,146.237 266,90 (5.325)261,579
288 P SSGCH 1,786,86 1,68.458 102,40 102.409
269 B2 6.200.007 5.830.695 369,313 (5.325)36.988
270
271
272
273 511 Manan of Stire
274 P SG 21.651,422 20.341.957 1.309,46 5.414 1.314.878
275 P SSGCH 862.871 813.418 49.45 (6)49.447
278 52 22.514.293 21.155.375 1.35.917 5,40 1.36.325
277
278 512 Mateanc of Bo Plnt
279 P SG 90.472.543 85,000,820 5,471.723 21,475 5.93.198
280 P SSGCH 3.997.56 3.768.461 229.108 (175)228.933
281 82 94,470.112 88.769.281 5.700.831 21.300 5,722.131
282
283 513 Maitenanc of Ele Plt
284 P SG 31.041,437 29.164.070 1.77,367 8.177 1.88.544
285 P SSGC 797.219 751,529 45.69 0 45.690
28 82 31.838.656 29.915.599 1,923.057 8,177 1,931.234
287
286 514 Mana of Misc. Stm Plant
28 P SG 9.395.33 8.827.114 568.224 1,897 570.121
29 P SSGH 2.55.029 2,40.539 148,491 (15)148.475
291 92 11.951.367 11.236.652 714.715 1.881 716.596
292
293 Totl Stam Powr G-.B2 854983,104 800,429,788 54553,317 2,063,632 56616,949
REVSED PROTOCOL Page 2.6
Vear-End
FERC BUS UNAUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
29 517 Operation Super & Engineering
295 p SG
29 82
297
298 518 Nuclar Fue Expens
299 p SE
300
301 82
302
303 519 Coant and Watè
304 p SG
305 82
306
307 520 Steam Expenses
308 p SG
309 82
310
311
312
313 52 Ele Exnss
314 p SG
315 82
316
317 524 Mise. Nur Exnss
318 p SG
319 82
320
321 52 Manace Supe & Enginri
322 P SG
323 82
324
325 52 Máan of Stnur32P SG
327 82
328
329 530 Ma of Reac Plant
330 p SG
331 B2
33233 531 Ma of Eltr Plan
334 P SG
335 82
336
337 532 Mainc of Mise Nu
338 P SG
339 B2
340
341 Tot Nuc_ Powr Genetio 82
342
343 535 Opeti Supr & Engeeng
344 P OGP
34 P SG 4.922.053 4.624.370 297.683 3.058 30.741
34 P SG 3.50.43 3.2.371 212.067 2,881 214.94
34734 82 8.428.491 7.918.742 509.750 5.939 515.689
34935 536 Water For Po
351 P OGP
352 P SG 146.55 137.692 8.864 32 8,89
35 P SG 70.22 65.98 4.248 4,248
3535 82 216,788 203.677 13.111 32 13,143
356
REVED PRTOCOL Page 2.7
Yea-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
357 537 Hyli Expense35P DGP
359 P SG 4.299.292 4.039,274 26,019 398 26.416
36 P SG 40.674 382.078 24,595 72 24.667
381
362 82 4.705.96 4,421.352 284,614 470 285.084
363
36 53 EIe Expenses36P DGP
36 P SG
36 P SG
36
369 82
370
371 53 MI. Hy Expe
372 P DGP
373 P SG 8.629.629 8.107.715 521.915 59.102 581.017
374 P SG 6.07.896 6.114.303 393.594 (3.315)39,279
375
376
377 82 15,137.525 14.222.017 915.50 55.788 971.296
378
379 54 Rent (Hy Geraio)
38 P DGP
381 P SG 34.192 32.125 2.068 2.058
382 P SG 11.233 10.554 679 (5)674
383
384 B2 45,426 42.678 2.747 (5)2.742
385
386 541 Mat Su & Engrig
387 P DGP
388 P SG
389 P SG
390
391 82
392
393 542 Ma of Slrs
394 P DGP
395 P SG 89.136 841.939 54.198 210 54.407
396 P SG 124.785 117.238 7.547 16 7.56
39739 82 1.020.921 959.176 61.745 226 61.971
3940
401
402
403 54 Mai of Dams & Watrwys40PDGP
40 P SG 730.03 68.884 44.152 26 44.420
40 P SG 287.859 270.45 17.410 655 16,06
40740 B2 1,017.895 956.333 61.562 923 62.485
409
410 54 Ma of Ele Plant
411 P DGP
412 P SG 1.129.86 1.051,533 68.334 613 68.947
413 P SG 54.628 515.44 33.181 359 33.53
414
415 82 1.678.49 1.576.980 101.514 972 102.48
416
417 545 Maintna of Mis. Hy Plånt
418 P DG
419 P SG 1.33,44 1.249.976 80.46 289 80,753
420 P SG m.42O 730.402 47,018 126 47.144
421
422 B2 2,107.860 1.980,378 127.482 415 127.897
423
424 Tot Hyraul Powr Genertion 82 34,359,368 32.281.335 2,078,033 64.759 2,142,792
REVSED PROTOCOL Page 2.8
Year-End
FERC BUS UNADJUSTD RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
425
426 546 OpraUon Supr & Engring
427 P SG 729.753 68.618 44.135 (1)44.134
428 P SSGCT
429 82 729.753 68.618 44.135 (1)44.134
43
431 547 FueloonPC
432 P SE
433 P SSCT
43 82
435
436 547NPC FuePC
437 P ,SE 261.141.9n 243.941.952 17.20,020 16.802.60 34.002.626
438 P SSECT 64.695.537 59.84.777 4.845.759 (2.583.107)2.262,653
439 82 325.837.509 303.791.n9 22.045.780 14.219,499 36.265.279
44
441 54 Gen Expense
442 P SG 11.819.36 11.104.538 714.828 2,03 716.70
44 P SSGCT 10.63.272 9.982.099 654.173 (491.457)162.716
44 B2 22.455.638 21.08.637 1.369,001 (489,15)879.586
4444 549 MIll Ot
447 P SG 5.931.46 5.572,735 35.731 1.168.027 1.52.758
44 P SSGCT
449 82 5,931,46 5.5n.735 358.731 1,168.027 1.526.758
45
451
45245
454 550 Ren
45 P SG 98.99 927.303 59.693 59.693
45 P SSCT 10,977,69 10.302.519 675.171 (382.825)292,347
457 B2 11.96.686 11.229.822 734.864 (382.825)352.040
45
459 551 Ma Supervion & Engg
46 P SG
481 82
46246 552 Mant of Str46P SG 339.85 319.30 20.55 22 2o.76
465 P SSGCT 276.119 259.137 16.982 (5.611)11.371
46 B2 615.974 578.437 37.537 (5.589)31.948
46746 553 Main of Generatio & Ele Pla
469 P SG 3.359.178 3,158.017 203,161 146,271 34.432
470 P SSGCT 1.271.491 1.193.289 78.202 (35.282)42.920
471 82 4,63.669 4.349.306 281.363 110.989 392.352
472
473 554 Matena of Mi Ot
474 P SG 113,44 106,587 6.861 7 6.868
475 P SSGCT 282.634 265.251 17.383 (8.328)9.055
476 B2 398.083 371.838 24.244 (8.321)15.923
477
478 Tot Other Powr Geertion B2 372,561,778 347,666.123 24.895,655 14,612.364 39,508.020
479
48
461 555 Pu Po-Non NPC
482 CMSC S (22.499.508)(17.131.485)(5.368.023)5.36.023
463 (22.49.508)(17.131.485)(5.368,23)5.368,23
484
485 55 Pud Powr-NPC
466 P SG 63.103,690 594.813.973 38.289.717 74.250.554 112,5.271
487 P SE 153.134,779 143.048.613 10.086,166 (4.44.945)5.645.221
48 Seasonal Co P SSGC 678,227 678,227
489 DGP
49 786,238.469 737.862.585 48.375.883 70.487.836 118.863.719
491
492 Totl Pu Pow 82 763.738.961 720.731.100 43.007.860 75.855.859 118.863,719
49349 558 Syste Co & Loa DIh
49 P SG 2.53.081 2.381.760 153.320 881 154.21
49
497 82 2.535.081 2.381.760 153.320 881 154.201
49849
REVSED PROTOC Page 2.9
Year-nd
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADJTOTAL
500
501 557 Otr Exnses
502 P S (183.792)(150.819)(32.973)6.70.00 6.37.026
503 P SG 59,521.272 55.~21.463 3.599,810 (441.694)3,158.116
504 P .SGCT 1.122.425 1.054.273 68,152 68.152
50 P SE
50 P SSGCT 82.718 77.631 5.088 (2,775)2.313
507 P TROJP
50
509 82 60.542.623 56.902.547 3.64.076 6.125.531 9.765.607
510
511 Embe Co Direnti
512 Company Ow ~ P DGP (112.142.820)(112.142.82)
513 Company Ow ~ P SG 112,142.820 105.360.492 6.782,328 6.782,328
514 Ml Co P Me (5Q.55,5)(49.857,411)(99,142)(99,142)
515 w-e Cotrct P SG 50,85.55 47.779.841 3.075.712 3.075.712
516 Existg OF Con P S 35,202.90 34.905.674 297.230 297.230
517 Exti OF Co P SG (35.202.90)(33.073.854)(2,129.050)(2, 129.50)
518
519 (7.028,078)7,28.078 7.028.78
520
521 Tot Other Pow Su B2 826.816.66 77,987.330 53.829.335 81.982.271 135.811,06
522
523 Totl Prouction Exe B2 2.088.720.914 1.953.364575 135.356.340 98.723.027 234,079,367
524
525
526 Sumar of Prn Ex by Facor
527 S 12.519.60 17.623.370 (5,103.767)11.38,023 6.34.256
528 SG 1.133.150.40 1.064.618.172 68.532.231 75.247.403 143,779.634
529 SE 94.133.48 88.684,892 62.44.45 14.036.589 76,48.045
53 SNPPH
531 TROJ
532 SGCT (122.425 1.05.273 68.152 68.152
53 DGP (112.142.82)(112.142.820)
534 DEU
535 DEP
538 SNPP
537 SN
538 DGU
539 MC (50,85.55)(49.857.411)(998.142)(99.142)
54 SSCT 23.526.92 22.079.926 1.44.99 (926.278)520.721
541 SSECT 64.695,537 59.849.777 4.84.759 (2.58.107)2.262.653
542 SS 678.227 678.227
543 SSGCH 16.404.169 15.46.017 94.152 (210)939.942
54 SSECH 52.166.876 48.99.378 3,176.498 332.381 3.50.878
54 Tota Prouc Expense by Fact 82 2.08.720.914 1.95.36.575 135,356.340 98,723,027 234,079.367
546 56 Opera Supeisio & Enering
547 T SG 8.207.35 7.710.975 49.375 141,782 83.157
5454 B2 8.27.350 7.710.975 49.375 141.782 638.157
55
551 561 Lo DI
55 T SG 7,88.745 7,411.83 477.106 12.814 489.920
55355 82 7,88.745 7.411.83 477,106 12.814 489.920
55 562 Sta Exse
55 T SG 1.00.028 94.184 60.84 319 61.163
55755 B2 1.006.028 945.184 60.844 319 61.163
55956 563 Over Li Exns
561 T SG 125.807 118.199 7.609 14 7.622
5656 B2 125.807 118.199 7.609 14 1,622
564
565 56 Unun Une Expese.56 T SG
567
568 82
56
REVSED PROTOCOL Page 2.10
Year-End
FERC BUS UNADUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADTOTAL
570 56 Trasmision of Electriit by Others
571 T SG
572 T SE
573
574
575 565NPC Trasmission of Elecricit by QtrsPC
576 T SG 104.789.310 98.451.718 6.337.592 856,270 7,193.863
577 T SE 1.802.80 1.684.059 118.741 (110.032)8.709
578 106.592.110 100.135,777 6.45.333 746.239 7.202.572
579
580 Tota Trasmisio of El by Other 82 106.592.110 100.135.777 6.56.333 746.239 7.22.572
581
582 56 Mi. Traission Expnse
58 T SG 2,751,804 2.58.377 166.427 (5.84)180.58
58458 82 2.751.804 2.585.377 166.427 (5.842)1$.586
586
587 567 Rents - Traissio
58 T SG 1.35.267 1.274,241 82026 129 82.155
589
590 B2 1.356.267 1.274.241 82.026 129 82.155
591
592 56 Ma Susi & Engeerig
.593 T SG 56.23 52.83 3.401 20 3,21
59
595 82 56.234 52.833 3,401 20 3.421
596
597 56 Matean of Strurs
598 T SG 3,233.567 3,038.003 195,564 1.551 197.115
59980 82 3,233.567 3.03.003 195.564 1.551 197,115
601
602 570 Ma of Sta Equent
603 T SG 9.272.545 8.711,747 56.798 4,413 ..210
60
605 82 9.272.545 8.711.747 56.798 4,413 56.210
60
607 571 Maten of Ovd Lins
60 T SG 13.323.841 12,51s.24 80.818 (433)80,3
609
610 82 13.323.841 12.518.024 605.18 (433)8õ5.385
611
612 572 Mate of Unde Lin
613 T SG (0)(0)
614
615 82 (0)(01
616 .
617 573 Ma of MI. Traissio Plnt
618 T SG 380.572 357.555 23.017 57 23.074
619
620 B2 380.572 357.55 23.017 57 23.074
621
622 Tot Transmision Expense B2 154,194872 144,859,554 9,335,318 901,06 10.236,380
623
624 Sumary of Transmi Expese by Fac
625 SE 1.802.80 1.68.059 118.741 (110.032)8.709
626 SG 152.392.072 143.175.495 9.216.578 1.011,09 ro.237.672
627 SNPT
--
628 Total Tramis Exnse by Fact 154.194.872 144.859.554 9.335.318 901.ö2 10.236.380
629 58 Operati Supervision & Engineerig
630 DP S 197.509 236.002 (38.492)11 (38.481)
631 DPW SNPD 19.530.50 18.616,01 914.508 (2.278)912.231
632 82 19.726.019 18.852.002 876.016 (2.266)873,750
633
634 581 Lod Ditcng
635 DPW S
63 DP SNPD 12,661.549 12.068.677 592.872 30.324 62.196
637 B2 12.661.549 12.06.677 592.872 30,324 623.196
63
639 582 Staon Exse
640 DPW S 3.361.261 3,187,322 173.939 1,266 175,04
641 DP SND 14,696 14.008 688 8 696
642 B2 3,375.957 3.201.330 174.627 1.273 175.900
64
REVISED PROTOCOL Page 2.11
Vear-E
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRJP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
64 58 Overh Lin Expenses64OPW S 6.970.60 6,802.998 167.601 1.60 169.401
64 OPW SNPD 642.038 611.975 30.63 262 30.325
647 62 7.612,638 7,414.974 197.664 2.061 199,726
64
649 584 Un Li Exse
650 OPW S 230.53 230.535
651 OPW SNP
652 B2 23.535 230.535
65365 58 Stt Lig & Sinal Sysms
65 OPW S
656 OPW SNPO 248.162 23.542 11,620 20 11,820
657 82 248,162 236,542 11.620 200 11.820
658
659 58 Meter Exnss
660 DP S 4.625,918 4,36.927 26.99 2.812 267.802
661 DP SNPO 1,169.500 1.114,739 54.761 552 55.313
662 82 5.795.418 5,475.666 319.752 3,364 323.115
6666 587 Cus Instlltin Exnse66DPWS 9.337.55 8.702.201 63,356 6,851 642.208
66 OPW SNO .
667 82 9.337.558 8.702,201 635.356 6,851 642.208
66
669 56 Mi. Ditr Expenses
670 DP S 2,742.204 2,535.001 207,20 1.316 20.52
671 OPW SNPD 6,35.655 6.059.007 297.648 8.554 30.201
672 82 9.098.86 8.594.008 504.852 9.869 514.721
673
674 589 Ren
675 DP S 3.921,526 3.872.49 49.029 38 49,6a
S76 DP SNP 36,40 351.155 17.250 17,25
677 B2 4,289,931 4.223.651 66.280 38 66,318
678
679 59 Mat Su & Enging
88 DP S 54.076 520.148 22.928 240 23.168
681 DPW SNPO 5.959.341 5.680.297 279,44 8,989 288.03
682 82 6.502,417 6,20,446 301,972 9.22 311.201
68366 591 Main of Stres66DP S 1,248.687 1,158.681 90.06 90.00
66 DPW SN 134.105 127.826 6,279 6,279
687 82 1.382.792 1.286.507 96,285 9ë.285
68868 592 Manano of Sta Equipment69DPS 9,975,48 9,621,68 353.775 3.179 35,95
691 DP SNP 1.768,399 1,66.594 82.805 12,619 95.424
89 82 11,743.862 11.307.282 436.579 15.798 452.377
693 59 Maintna of Ovad Un
694 DPW S 69.826.662 84.86.111 4,961.551 24.425 4,98.975
695 DPW SNP 1.68.189 1,601.515 78,674 1.120 79.794
696 82 91.506.851 86.466.626 5.040.225 25.54 5.065.769
697
698 594 Mate of Unun Lines
699 DPW S 22.772.712 22,023.721 748.99 5,779 754.770
70 DP SNP 28,951 27.59 1,356 12 1.367
701 B2 22.801.66 22,051.317 750.346 5.791 756.137
702
703 595 . Mai of Lin Trasfoer
704 DP S 60.688 60,668
705 DP SNP 66.276 65.235 32.041 261 32.302
706 82 744,964 712.923 32.041 261 32.302
707
708 596 Ma of Str Ligng & Si Sys.
709 OPW S 4,33.96 4.170,152 165,812 U60 167,472
710 DPW SN
711 B2 4.33.96 4.170.152 165.812 1.660 167,472
712
REVSED PROTOCOL Page 2.12
Year-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
713 597 Maintenance of Meters
714 DPW S 3.95,999 3.672.402 284.598 3.067 281,66
715 DPW SNPD 1.519.486 1.44.337 71.149 713 71.862
716 82 5.476.48 5.120.738 355,747 3.780 359.527
717
718 598 Maint of Misc. Distrbu Plant
719 DPW S 3.487.765 3.44.380 39,384 136 39.520
720 DPW SNPD 979.485 933.621 45.864 (36.46)9.818
721 82 4.467,250 4,382.001 85.248 (35.910)49.339
722
723 Totl DIstribution Expese B2 221.34.872 210.697,578 10,64,294 77,869 10,721.162
724
725
726 Sumary of Distrbuion Exse by Facor
727 S 167.595.125 159.46.455 8.126.671 52.579 8,179,249
728 SNPD 53.745,747 51,22,124 2.516.623 25.290 2,51.913
729
730 Tota Distribution Expnse by Fact 221.340.82 210.697,578 10.643.294 77.86 10,721,162
731
732 901 Supeision
733 CUST S 262.967 252.277 10,689 115 10.80
734 CUST CN 2.49.732 2.392,393 101.339 772 102.111
735 B2 2.756.699 2.644.670 112.029 887 112.916
736
737 902 Mete Readig Expse
738 CUST S 27.323.838 25,747,110 1.576.728 15.98 1.59.714
739 CUST CN 844.132 809.829 34,303 279 34,583
740 82 28,167.970 26.556.939 1.611,031 16.266 1,627.297
741
742 903 Customer Recip & Collctons
743 CUST S 6,419,019 6.191.137 227,882 2.395 230.277
744 CUST CN 49.188.818 47.189.905 1,998.914 5.192 2.00,105
745 B2 55.607.837 53.381,042 2.226.795 7.587 2.234.382
746
741 904 tJ Acunts
748 CUST S 9,36.544 9.022.016 341.528 341.28
749 P SG
750 CUST CN (812.507)(79.489)(33.018)32.510 (50)
751 82 8.551.037 8.242.527 308.510 32.510 341.020
752
753 905 Mi. Cusr Acunts Expense
754 CUST S 3.768 3,768
755 CUST CN 370,476 355,420 15,055 88 15.143
756 82 374.243 359.188 15.055 88 15.143
757
758 Tot Customer Ac:counts Expense B2 95,457.786 91,184366 4,273,420 57,338 4.330.758
759
760 Summary of Cusmer Ac Ex by Factor
761 S 43.373,135 41.216,30 2.156.827 18,497 2.175.324.
762 CN 52.084,65 49,96.057 2,116.593 38.841 2.155.43
763 SG .--
764 Total Customer Acunts Exse by Facr 95.457,786 91,184.366 4.273.420 57,338 4.33.758
765
766 907 Supisi
767 CUST S
768 CUST CN 423.544 40332 17.212 161 17,373
769 82 423.544 40,332 17.212 161 17.373
770
771 908 Custoer Assitanc
772 CUST S 38.718.172 35,171,471 3,54,701 (2.04.335)1.503,36
773 CUST CN 4.038.065 3.873.96 164,097 1.49 165,92
774
775
776 82 42.756.237 39.04.439 3,710.798 (2.041.840)1,66.958
777
REVSED PROTOCOL Page 2.13
Yeand
FERC BUS UNADJUSTD RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
778 909 Informatinal & Instrtional Ad
779 CUST S 629.957 618.253 11.705 (8.280)3.424
780 CUST CN 3.154.588 3.026.394 128.195 (3.180)125.015
781 82 3.784.546 3.64.64 139.899 (11.46)128.439
782
783 910 ~sc. CuskKer Serv~e
784 CUST S 2.00 1.376 624 624
785 CUST CN 3.126 2.99 127 127
786
787 82 5.126 4.375 751 751
788
789 Tot Custome Service Expee B2 46.969,452 43,100,792 3,868.660 (2.053.139)1,815.521
790
791
792 Sumar of Cuser Seric Exp by Fac
793 S 39.350.128 35.791.099 3.559.029 (2.051.615)1.507.414
794 CN 7.619.324 7.309.693 309.631 (1.52)308.107
795
796 Tot Custmer Se Ex by Fac 82 46.969.452 43.100.792 3.868.660 (2.053.139)1.815.521
797
79879 911 Suprv
800 CUST S
801 CUST CN
802 82
80380 912 Deonti & Se Expense80CUSTS
80 CUST CN
807 B2
808
809 913 Adert Expe
810 CUST S
811 CUST CN
812 82
813
814 916 Mi Sa Expe
815 CUST S
816 CUST CN
817 82
818
819 Tot sa Expee 82
820
821
822 Tota Sa Expe by Fac
823 S
824 CN
825 Tota5as Exnse by Facor
826
827 Tot Cusr Seic Exp IncludIng Sale B2 46,969.452 43,100,792 3,868.660 (2,053.139)1,815.521
828 92 Administrtiv & Genera Salaris82PTOS 351,795 351.795
830 CUST CN
831 PTO SO 82.94.771 78.175.00 4.774.171 (189.216)4.58.955
832 B2 83.301.56 78.527.395 4.774.171 (189,216)4.58.955
8383 921 Of Sus & expns
835 PTO S (937.48)(93.90)1.425 (1,2)161
83 CUST eN
83 PTD SO 12.717.213 11.98.274 731.939 (18.87)713.352
838 B2 11.779.729 11.046.365 733.364 (19.851)713.513
83984 92 A&G Exns Tra
841 PTD S
842 CUST CN
84 PTD SO (20.697.805)(19.50.543)(1.191.261)36.885 (1.154.576)
64 82 (2O.697.805¡(19.506.543)(1.191.261)36.685 (1.154.576)
84
REVIS PROTOCOL Page 2.14
Vear-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTENT ADTOTAL
846 923 Oue Servs
847 PTO 5 40.783 40.783
84 CU5T CN
849 PTO 50 9.759.436 9.197.732 561.704 (12.697)549.007
850 62 9.800.219 9.238.515 561.704 (12.697)549.007
851
852 924 Prort Insura
853 PTO 50 24.516.013 23,104.995 1.411.018 1.411.018
854 B2 24.516.013 23,104.995 1.411.018 1,411.018
85
856 925 Injuris & Damags
857 PTO 50 11.291,287 10.641.418 649.870 (147.112)502.757
858 B2 11,291.287 10.641.418 649.870 (147.112)502.757
859
860 926 Emple Pensis & Befi
861 LABOR 5
862 CU5T CN
863 LABOR 50
864 B2
865
866 927 Fraise Requirments
867 OM5C 5
868 DM 50
869 B2
870
871 928 Relat Comision Exnse
872 DMC 5 8.088.821 7.760,05 328.764 32,764
873 CU5T CN
874 OM5C SO 407 38 23 23
875 FERC 5G 1.922,411 1,80.145 116.26 (142.341)(26.075)
876 62 10.011.639 9,566.585 44.054 . (142.341)302.713
877
878 929 Duplte Chrgs
879 LABOR 5
88 LABOR SO ~5.845.341 (5.50.912)(33.428)(48)ff.914)
881 B2 5.845,340 (5.508.912Î (33,428)(486)(336.914)
882
883 93 MI Ge Exses
864 PTO S 12.190.297 12,189.673 624 171.98 \72.612
885 CUST CN 5.724 5,491 233 233
88 LA SO 13.372.148 12,602.514 789.63 96.143 1.734.777
887 62 25.568.169 24,797.679 770.490 1.137.131 1.907.622
88888 931 Ren
890 PT S 902.697 902.697
891 PTO SO 5.389.807 5.079.597 310.210 (29.05)281.161
892 B2 6.292.504 5.982.294 310.210 (29.050)281.161
893
894 93 Maien of Geera Plant
895 G S 42.149 42.149
896 CUST CN
897 G SO 24.29.341 22.897.96 1.398.375 3.014 1.401.38
898 B2 24.338.489 22.940.114 1.398.375 3.014 1.401.389
899
900 Totl Administrative & Genral Expense B2 180.356,471 170,829.90 9,526,567 636,078 10,162,64
901
902 Summary of A&G E¡pe by Facr
903 S 20.679.057 20.34,243 33.814 170.724 501.538
904 SO 157.749.278 148.670.024 9.079.255 607.696 9.88.95
905 SO 1.22.411 1.80.145 116,2 (142.341)(26.075)
90 CN 5.724 5.491 233 .23
907 Total A&G Expns by Fact 180.35.471 170.829.904 9,526.567 63.078 10.162.646
908
909 Totl O&M Expense 82 2,787,040,368 2,614,036,769 17,003.599 98,342,235 271,345.834
REVIED PRTOCOL Page 2.15
Vear-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
910 403SP Steam Depriation
911 P SG 37.507.935 35.239,478 2.268.457 2.2.457
912 P SG 40.335.873 37.896.384 2.439.488 2.43.488
913 P 5G 60.60.591 56.941.142 3.66.449 (2.558.453)1.106.996
914 P SSGCH 9.113.517 8.591.205 522.312 (32.405)48.907
915 63 147.563.915 138.66.209 8.895.706 (2.590.858)6.304.848
916
917 403NP N1lear Depriati
918 P 5G
919 B3
920
921 40HP Hy Detin
922 P 5G 4.979.312 4.678.166 301.146 301.146
923 P 5G 1.187.40 1.115.587 71.813 71.813
924 P SG 5,276.56 4.957.44 319.124 42.770 361.94
925 P 5G 1.477.96 1.388.571 89.38 93.765 183.151
926 B3 12.921.243 12.139.714 781.469 136.535 918.004
92792 4030 Ot Pro Deat92P 5G 39.783 37.377 2.40 2.40
93 P 5G 29.280.267 27.50.415 1.770.652 1.912.013 3.682.86
931 P SSGCT 3.161.55 2.967.106 194.44 (35.763)158.68
932 P S5GCH
933 B3 32.481.604 3õ.513.898 1.967.706 1.876.250 3.84.956
93493 40TP Tl'is Depn
93 T SG 12,70.765 11.528.637 742.128 742.126
937 T SG 13.361.64 12.55.542 808.104 80.104
938 T 5G 31.738.237 29.818.728 1.919.509 5.94 1.92.452
939 B3 57.370.64 . 53.900.907 3.469.741 5.94 3.475.684
94
941
94294 403 Dist Depn
94 360 .....AIOPW S 274.80 257.336 17.46 17.46
94 361 s_DP 5 933.033 918.355 14.678 14.678
94 36 _I! DP 5 14.029.40 13.65.65 374.754 374.754
947 363 _--_DPW 5 142.101 142.101
94 36 _&T_ DP S 34.352.246 32.28.44 2.06.806 (237.774)1.31.032
949 365 OH Co DP 5 16.530.64 15.64.682 881.962 881.962
950 36 UGei OPW S 6.473.43 6.319.003 154.436 154.43
951 367 UG~DP 5 13.788.82 13.327.754 461.073 461.073
952 368 .UnT..OPW S 23.342.420 21.974.708 1.367.712 1.367.712
95 369 Se OPW 5 9.972.44 9.43.963 533.48 533.48
954 370 ~OPW 5 6.471.780 6.014.80 45.974 45.974
95 371 ..Cu_DP 5 379.042 371.712 7,270 7.270
95 372 ~~OPW S 1.29 1.168 127 127
957 373 -t.OPW S ,2.373.614 2.341.318 32.296 32.29
958 83 129.065.095 122.694.059 6.371.036 (237.774). 6.133.262
95996 40 Gera Dereti
961 G-TUS S 12.94.217 12.073.43 86.780 (89.186)777.594
962 PT SG 469.20 44.632 28.377 28.371
963 PT 5G 807.216 758,3 48.820 48.820
964 P SE 37.603 35.126 2.471 (39)2,438
96 CUST eN 1.384.927 1.328.647 56.28 (2825)53.45
96 G-SG 4.911.245 4.614.216 297.029 (28.262)268.767
967 PTD 50 17.641.227 16.625.887 1.015.34 (30.297)985.043
968 G-G SSGCT 16.958 15.915 1.04 (32)1.011
969 G-G SS 170.708 160.92 9.784 (857)8.92
970 63 38.379.310 36.053.379 2.325.930 (151.499)2.174.432
971
972 403GO'Gera Vehi
973 G-5G
974 B3
975
976 40 MIg Deti
977 P SE
978 B3
979
REVISED PROTOCOL Page 2.16
Year-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER'IDAHO ADJUSTMENT AO TOTAL
980 403EP Exrimental Plant Depreciation
981 P SG
982 P SG
983 63
98 4031 ARO Deiation
985 P S
986 63
987
988
989 Total Depriation Expense B3 417,781,814 393,970,225 23.811.589 (961.402)22.850.187
99
991 Summary S 142,00.312 134.767.495 7.237.617 (326.961)6.910.85
992 DGP
993 DGU
994 SG 244.250.008 22.477.92 14.7n.089 (532.223)14.23.865
995 SO 17.641.227 16.625,887 1.015.34 (30.297)985.43
996 CN 1.38.927 1.328.647 56.280 (2.825)53.45
997 SE 37.603 35.126 2,477 (39)2.43
99 SSGCH 9.284.225 8.752.130 532.096 (33.262)498.834
999 SSGCT 3.178.513 2.983.022 195.491 ~35.795)159.696
100 Total Deprtin Expense 6y Fac 417.781.814 393.970.225 23.811,589 (61.402)22.850,187
1001
1002 40GP Amort of L T Plat - Capital Lease Gan
1003 !-SITUS S 967,674 967.674
1004 loS SG
1005 PTO SO 1.708,80 1.610.45 98.35 96.350
1006 P SG
1007 CUST CN 232.427 222,982 9.44 9.44
1008 P SG
1009 84 2.908.901 2.801.106 107.795 107.795
1010
1011 404S Amo of L T Plant - Ca Lea Steam
1012 P SG
1013 P SG
1014 64
1015
1016 401P Am of L T Plat - Intib Plt
1017 !-ITUS S 38.191 17.790 20.401 20.401
1018 P SE 3,711 3.46 244 244
1019 I-SO SG 6,479.693 6,087.805 391.88 391.8
1020 PTO SO 28.791.417 27,134.328 1.657,089 (7.138)1,64.951
1021 CUST CN 4.849,670 4.652.591 197,079 197.079
1022 I-SO SG 2.057.08 1,932,673 124.411 22.107 34.518
1023 I-SG SG 30.68 29.95 18.730 18.730
1024 P SG
1025 loS SOOCT
1026 loS SSGCH 5.777 5.44 331 331
1027 P SG 17.884 16.802 1.082 1.082
1028 B4 42.553.115 40.141.860 2,411.255 214.969 2.626,223
1029
1030 404MP Am of L T Plant - Mi Plat
1031 P SE
1032 64
103
1034 4040 Amor of L T Plant. Ot Plant
1035 P SSGCT 293,921 275.84 18.077 (10.598)7.480
1036 B4 293.921 275.844 18.077 (10.598)7.480
1037
1038
1039 404HP Amorization of Otr Elecc Plant
1040 P SG 2.284 2.146 138 138
1041 P SO 38,242 35.92 2.313 2.313
1042 P SG
1043 B4 40,526 38.075 2,451 2.451
1044
1045 Total Amortization of Limit Ter Plant B4 45796.464 43.256,886 2.539.578 204.371 2,743,949
104
1047
104 405 Amortti of Ot Elric Plant
1049 GP S
105
1051 B4
1052
REVISED PROTOCOL Pag 2.17
Year-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNe . FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADJTDTAL
1053 40 Amortion of Plant Acquisition Adj
1054 P S
1055 P SG
1056 P SG
1051 P SG 5,419.353 5.141.96 331.388 331,388
1058 P SO
1059 84 5.419.353 5.141.965 331.388 331,388
106 407 Amort of Pro Losss. Unr Plant. etc
1061 DPW S 9,152.248 9.152.248
106 GP SO
106 P SG-180.128 132.94 47.182 (41,182)
1064 P SE
1065 P SG 33,105 312.959 20.146 20,146
1066 P TRDJP 2.016.153 1.892.56 123.585 123.585
1061 84 12.881.634 12,690,121 190,913 (41.182)143,131
106
1069 Tot Amoiztion Expese B4 64,157,451 61,095,512 3,061.819 157,189 3,219,068
1070
1011
1012
1013 Sumary of Amor Expese by Fac
1014 S 10,158.114 10.131.113 20.401 20.401
1015 SE 3,111 3.46 244 244
1016 TRDJ 2.016,153 1,892,56 123,58 123.58
1017 DGP
1078 DGU
1019 so 30.50,211 28.144,178 1.155.439 (1.138)1.748.301
108 SST 29,921 215.84 18.017 (10,598)1,48
1081 SSGCH 5,m 5,44 331 331
1062 CN 5,06.091 4.875.513 206.524 206.524
1083 SG 14.111.333 13.821.231 890.095 22,107 1,112.202
108 Tot Amzati Expese by Factr 63.377,323 60,36.626 3.014.697 20.371 3.219,08
108 40 Taxes Ot Than Incme
106 DM S 23.301.291 23.301.291
1081 GP GPS 69,102.426 65.125,23 3.917.188 601.911 4.58,159
106 GP SO 8.523.359 8,032,198 490.562 49.562
1069 P SE 54.66 50.124 35.94 35.94
109 P SG
1091 DM OPRV-IO
1092 GP EXCTAX
1093 GP SG
1094
1095
1098
1091 Tot Taxes Other Than incoe B5 101,472.741 96.969,058 4,503.690 607.971 5;11.661
109
109
1100 41140 Defe Inv Tax Credi. Fed
1101 PTO DGU (5.854,86)(5,141.169)(701.091)48.641 (218,44)
1102
1103 81 (5.854.86)(5.141.169)(101.091)488.641 (218.445)
1104
1105 41141 Defe Instt Tax Cr - Idah
1106 PT OGU
1101
1106 81
1109
1110 Tot De ITC B1 (5,854.86)(5,147,169)(71,091)48,641 (218,445)
1111
REVISED PROTOCOL Pag 2.18
Year.End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO.ADJUSTMENT ADJTOTAL
1112
1113 427 Intrest on Long- Term Debt
1114 GP S 3,354.85 3.35.855
1115 GP SNP 278.731.910 263,025.694 15.706.216 15.706.216
1116 B6 278.731.910 263.025.694 15.706.216 3.354.85 19.061,071
1117
1118 428 Amoron of Debt Disc & Ex
1119 GP SNP 7.664,485 7.232.601 431,885 431.88
1120 B6 7.66.48 7.232.601 431.885 431.885
1121
1122 429 Amoron of Preium on Debt
1123 GP SNP (58.88)(55.56)(3.318)(3.318)
1124 B6 (58.884)(55.566)(3.318)(3.318)
1125
1126 431 Oter Intere Expens
1127 NUTtL OTH
1128 GP SO
1129 GP SNP 29.764.58 28.087.38 1.677.199 1.677.199
1130 B6 29.764.583 28,087.383 1.677.199 1.77.199
1131
1132 43 AFUD - Bo
1133 GP SNP (28.65,980)(27.039.362)(1.614.618)(1.614.618)
1134 (28.65.98)(27.039.362)(1.614.618)(1.614.618)
1135
1136 Tot Elee. Interest Dens for Tax B6 287.44.113 271.25.749 16,197.36 3.354.855 19.552.219
1137
1138 NonUti Portn of Interst
1139 427 NUTIL NUTL
1140 428 NUTIL NUTIL
1141 429 NUTIL NUT
1142 431 NUTIL NUTIL
1143
1144 Tot NoIH Intst
1145
1148 T otinrest D8on fo Tax B6 287.44.113 271.250.749 16,197.364 3.354,855 19.552.219
1147
1148
1149 419 In & Dids
1150 GP S
1151 GP SNP
l 4O.906.60l 138.601.052)12.305.009)12.85.(0)1152 Tot Opti Dedus for Tax B6 40.906.060 38.601.052)2.305.009)P05.0ö9)
1153
1154
1155 41010 Defe In Tax. Fedral-
1156 GP S 359.730.45 34.857.39 13.873.05 (706,029)13.167,30
1157 P TROJO 14.85 13.758 901 901
1158 PT DGP 2.43 2.43
1159 LAOR SO 37.617,391 35.45.323 2,185.06 (286.69)1.878.374
1160 GP SNP 21.316 20.115 1.201 1.201
1161 P SE 7.127.36 6.857.927 469.441 (5.423)46.018
1162 PT SG 7.66;825 7,205.19 463.08 (46.027)(2.22)
1163 GP GPS 1.001 94 58 58
1164 OlTEX OITEX 2,373.50 2,373.5
1165 CUST BAEBT 1.87.36 1.819.28 68.09 68.09
1166 CUST CN 23,817 22.849 968 96
1167 P IBT 121.199 117,55 3.64 5.607 9,22
1168 OPW SND
1169 B7 414.215.852 397.169.611 17.046.240 914.939 17,961,179
1170
REVSED PROTOOL Pag 2.19
Veand
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADTOTAL
1171
1172
1173 41110 Defemi Ince Tax - FedraI-R
1174 GP 5 (290.988.771)(279.583.593)(11.40.178)248.600 (11.156.578)
1175 P 5E (7.43.238)(6.94.848)(48.390)7.144 (482.246)
1176 PT DGP (300,173)(30.173)
1177 GP SNP (1.765,373)(1.66.896)(99,477)(99,477
1178 PT 5G (11.033.42)(10.36.126)(667.294)248.904 (418.91)
1179 GP GP5 (531,558)(50.96)(30.594)(30.594)
1180 LABOR SO (22.243.997)(20.96.744)(1.280.253)29.468 (981.784)
1181 PT 5NPO (38,879)(37.059)(1.820)(1,820)
1182 CUST CN
1183 P SGCT (356.221)(334.592)(21.629)(21.29)
1184 DITEX DITEX 845.208 845.208
1185 P TROJO (581,63)(54,89)(35.737)(35.737)
1186 P SSCH
1187
1188
1189 B7 (335.270.262)(321.238,890)(14.031.372)1.64.325 (12.383.047)
1190
1191 Tot Derr Inom Tax..B7 78.9.59 75,930,n1 3.014.869 2,583.264 5,578.132
1192 SCF Adds - Flo Thrugh
1193 5CHMAF 5
1194 SCHF SNP
1195 5CHMAF 50
1196 SCHMF 5E
1197 SCHMF TROJ
1196 5CHMF SG
1199 B6
120
1201 SC Add - Peian
1202 P S
1203 P 5E 87.039 81.30 5,733 5.733
120 LAR SNP 1.09,54 1.03.755 61.789 61,789
120 SCP-S 50 11.167.89 10.525.123 642.768 642.788
120 SCMAP 5G 119,015 111,17 7.196 7,198
1207 DP BABT
120 B6 12,470,488 11.753.00 717,487 717.487
120
1210 SCHMT Ad . Temry
1211 SCHMT-SITUS 5 29.272.03 28.462.675 80,3 (1.249,326)(43.962)
1212 P SSCH
1213 DPW ClAC 65,63.740 62.56.232 3.073.50 3,073,50
1214 5CHT-SP SNP 60,771.288 57.34.895 3,424,391 3.424.391
1215 P TROJO 1,532.58 1.43.421 94.165 94.165
1216 P SG
1217 SCT-Se 5E 19.578,50 18.288.78 1.289.531 186.211 1.455.743
1218 P 5G 26.819.66 27.076.66 1.742.99 (50.528)1.237.461
1219 SCHT-GPS GP5 1,40.646 1.320.031 80.614 80.14
1220 5CHMT-S0 50 15.68.29 14,777.819 902,479 (26,33)876.146
1221 SCHT-SNP 5NPD 29.370.967 27.995.83 1.375.284 1.375,284
122 CUT CN
1223 P 5GCT 938,633 881.64 58.993 56.99
1224 BOODEPR SCHMEX 49.661.101 467.410.161 28.25.340 (64,137)27.60.203
122 B6 148.664,46 707.564.802 41.099.66 (2.263.113)38.36.551
1228
1227 TOTAL SCHEDUE. M ADDITIO B6 761.134.953 719.317.802 41.817,151 (2.26.113)39,554.038
122
REVISED PROTOCOL Page 2.20
Year.End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
1229 SCHMDF Deuctins - Flow Through
1230 SCHMDF S
1231 SCHMDF DGP
1232 SCHMDF DGU
1233 B6
1234 SCHMO Deuctns. Permanent
1235 SCHMDP S
1236 P SE 4.39.479 4,105.973 289.507 289.07
1237 PTO SNP 381.063 359.591 21.472 21.472
123 SCHMDP 18T
1239 P SG 10.90.494 10.241.238 659.255 (659.25)(0)
1240 SCHMP-S SO 25.050.142 23,608.382 1.441.760 1.441.760
1241 B6 40.727.178 38.315.184 2.411.994 (659.255)1.752.739
1242
1243 SCHMDT Dedutions - Tempory
1244 GP S 68.145.601 66.29.851 1.849,750 (2.470,570)(62o.20)
1245 DPW 8AODE8T 4.973.203 4.793.777 179,426 179,426
1246 SCHMOT-5NP SNP 62,812.29 59.272,895 3,539.399 3.539.39
1247 SCHMOT CN 62.756 60.206 2.55 2.55
1248 SCHMT TROJD 38.625 36.252 2.373 2.373
1249 CUST DGP 6.423 6,23
1250 P SE 22.94.826 21.43.441 1.511.38 114.901 1.626.285
1251 SCHMT-5G SG 12.022.379 11.295.273 727.106 (878.222)(151.116)
1252 SCHMDT-GPS GPS 66.94.561 63.87.799 3,852.762 (189.778)3.682.98
1253 SCHMDT-50 SO 60.098.279 56.63,324 3.45.95 (57.257)3.401.697
125 TAXPR TAXEPR 60.113.141 569.144.970 34.96.171 7.569.532 42.537,703
125 DP SNPD
1256 B6 902,160.088 852.068.212 50,091.877 4.088.605 54.180.482
1257
1258 TOTAL SCHEDULE - M DEDUCTIONS B6 942.887.266 890.383.395 52.503.871 3,429.350 55.933.221
1259
1280 TOTAL SCHEDULE. M ADJUSTMENTS B6 (181.752.313)(171,065,593)(10,686,720)(5,692,463)(16.379,183)
1261
1262
126
1264 40911 Stae Ine Taxes
1265 18T I8T 23.501.83 22.79.027 706.805 (214.30)49.49
1266 18T SE (3,062)(3,06)
1267 REC P SG (34.513)(34.513)
1268 IBT 18T --.
1269 Totl State Tax Expense 23,501,832 22,795.027 706,805 (251.884)45,921
1270
1271
1272 C8ulio of Taxe Incme:
1273 Operati Revenus 4.242,281.360 3.99.771.360 242.510.000 102.96.324 34.476.324
1274 Oprating Deductions:
1275 o & M Exnses 2.787.040.368 2.614.036,769 173.003.599 98,34.235 271.345.834
1276 Deiation Expnse 417.781.814 393.970.225 23,811,589 (961.402)22.85.187
1277 Amortti Expense 64,157.451 61.09.572 3.061.879 157.189 3.219.88
1278 Taxes Otr Than Incme 101.472.747 96.96.058 4.503.690 607,971 . 5.111,661
1279 Intest & DIvidends (AFUDquit)(40.90.060)(38,601,052)(2.305.009)(2.30,009)
1260 Mise Reveue & Expense (11.343,723)(10.60.194)(734.528)493,472 (241,057)
1281 Total Operating Deductios 3.318.202.597 3.116,861.378 201.341.219 98.639,465 299.98.685
1282 Ot Deuctios:. .
1283 Intest Deuctions 287.44.113 271.250,749 16,197.36 3.354.85 19.552.219
1284 Interst on PCR8S
1285 Scle M Adjustments (181,752.313)(171,065.593)(10.68.720)(5,692.46)(16.379.183)
1286
1287 Incme Befo State Taxes 45,878.336 44.593,64 14,284.697 (4.720.459) .9.564.238
1268
1289 State Incme Taxes 23.501.832 22.79.027 706.805 (251.884)45.921
1290
1291 Tot Taxbl Ince 431.376.504 417.798.612 13.577.892 (4.46.575)9.109.317
1292
129 TaxRale 35.0%35.0%35.0%35.0%35.0%
129
1295 Fed Ince Tax. C8ulate 150.981.776 146.229.514 4.752.262 (1.564,001)3.186.21
129
1297 Adjents to Calclated Tax:
1298 40910 PMI P SE
129 40910 REC P SG (1;777.590)(1,m,S90)
130 4010 P SO
1301 40910 IAS_LABOR S
1302 Federal Income Tax Expense 1 .229,514 4, 52,262 3.341,591),671
1303130 Totl Operating Expenses 3,606,682.995 3,395,269.923 211.413.072 98.097,901 309.510.973
REVISED PROTOCOL Page 2.21
Yea.End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADTOTAL
1305 310 Land an Land Rights
1306 P SG 2.329.517 2.188.630 140.888 140.88
1307 P SG 34.798.44 32.693.857 2.104.58 2.104.588
130 P SG 52.841.353 49.64.541 3.195.812 3.195.812
1309 P S
1310 P SSGCH 1.246.36 1.174.932 71.431 71,431
1311 B8 91.215.679 85.702.959 5.512.720 5.512.720
1312
1313 311 St and Imprments
1314 P SG 235.66.00 22.849.363 14.216.646 14.216.64
1315 P SG 32.521.96 30.65.160 19.668.8 19.86.80
1318 P SG 186.828.179 175.528.927 11.2.252 (176.928)11.122,324
1317 P SSGCH 53,32.033 .49.992.672 3,39.361 3.039.361
1318 B8 803.44.185 755.024.122 48.424.063 (176.928)48.247,135
1319
1320 312 Boil Plant Eqipent
1321 P SG 730.217.780 66.054.663 44.163.117 44.163.117
132 P SG 667.820.168 627.43.820 40.38.348 40.3&.348
1323 P SG 1.16.54.716 1.142.965.90 73.575.625 1.508.243 75.083.869
1324 P SSGCH 227.303.718 214.276.533 13.027.185 10.480.704 23.507.889
1325 B8 2.841.882.382 2.670.727.107 171.155.275 11.98.948 183.144,223
1326
1327 314 Turt Unts
1328 P SG 147.50.489 138.58.491 8.92.979 8.92.979
1329 P SG 145.269.412 136.48.60 8.785.804 8.785.80
133 P SG 407.154.283 382.529.845 24.624.43 24.624.43
1331 P SSH 54.788.625 51.64.590 3.140.035 3.140.035
1332 B8 754.716.789 709.245.535 45.471.254 45.471.254
1333
1334 315 Acss Eletr Eqpmen
1335 .p SG 88.157,59 82.825.375 5.331.684 5.331.684
1336 P SG 139.35.575 130.930,2 8.428.320 8,428.320
1337 P SG 68.125.707 64.00;507 4.120.20 4.120.20
1338 P SSGCH 46.98.801 44.292.96 2.692.841 2.692.841
1339 B8 342.627.142 322.054.097 20.573.045 20.573,045
134
1341
1342134 316 MJ Po Pl Equipnt
134 p SG 4.918.591 4.621.118 297.73 297.473
134 P SG 5.327.245 5.00.05 322.188 32188
134 P SG 12.510.93 11.754.276 756.653 756.653
1347 P SSGC 3.144.722 2,96.492 180.23 180.230
134 B8 25.901.487 24.34.942 1.55.545 1.556.545
134
135 317 Steam Pl ARO
1351 P S
1352 B8
135
1354 SP Uncl St Pl. Ac 300
1355 P SG 526,307 49.476 31.831 31.831
1356 B8 526.307 49.476 31.831 31.831
1357
1358
13.59 Tot St Proction Plant B8 4,86.317,970 4,567,59.238 292,724.732 11.812.020 304.536.752
136
1361
136 Sumary of Steam Pro Pla by Fac
136 S
1384 DGP
136 DGU
136 SG 4.473.816.709 4.20.243.059 270.573,651 1.331.316 271.90.966
1367 SSCH 36.501.261 364.35.179 22.151.082 10.48.704 32.631.786
136 Tota St Prouc Pl by Facr 4.86.317.970 4.567.593,238 292.724.732 11.812.020 åö4.536.752
138 320 La an Lan Rits
1370 P SG
1371 P SG
1372 B8
1373
1374 321 Str an Iments
1375 P SG
1376 P SG B8
13n
, REVISED PROTOCOL Page 2.22
Year-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1378
1379 32 Reacr Pla Equipment
138 P SG
1381 P SG
1382 B8
138
138 323 Turbenrator Unit
1385 P SG
1386 P SG
1387 B8
138
1389 324 Land an Lan Rights
1390 P SG
1391 P SG
1392 B8
1393
139 325 Misc. Por Plant Equient
1395 P SG
139 P SG
1397 B8
139
1399
140 NP Unssd Nu Plan. Acc 30
1401 P SG'
1402 B8
1403
140140 Tot Nulear Proucio Plat B8
140
1407
140
140 Sumar of Nuclear Proti Pl by Facr
1410 DGP
1411 DGU
1412 SG
'1413
1414 T ol Nuar Pla by Fac
1415
1416 330 La an Lan RI
1417 P SG 10.626.875 9.98.169 842.707 842.70
1418 P SG 5.307.562 4.986.564 320.99 32.99
1419 P SG 3.122.410 2.93.569 188.841 188.841
1420 P SG 635.700 597.253 38.447 38.447
1421 B8 19.692.547 18.501.554 1.190.993 1.190.993
1422
1423 331 Sts an Imprements
1424 P SG 21.461.160 20.163.20 1:1.7.95 1.297.95
1425 P SG 5.327.119 5.00.93 32.181 32.181
1426 P'SG 50.016.734 46.991.753 3.024.981 3.024.981
1427 P SG 7.101.54 6.672.047 429.497 429.497
1428 B8 83.90.557 78.831.941 5.074.616 5.674.616
1429
1430 332 Rese. Dams & Wateys
1431 P SG 151.44.54 142.473.175 9.171.368 9.171,3
1432 P SG 20.315.731 19.087.0:1.228.883 1.22.883
143 P SG 74.756.625 70.235.391 4.521.234 958.413 5.479.647
1434 P SG 33.26.922 31.254.96 2.011.96 58.114 2.592.077
1435 B8 279.98.821 263.050.574 16.933.247 1.538.527 18,471.774
1436
1437 33 Wat Wh. Tur. & Genetor
143 P SG 32.83.723 30.847.96 1.98.763 1.98.763
1439 P SG 9.479.349 8.90.044 573.305 573.305
144 P SG 35.531.537 33.3.612 2.146.925 2.146.92
1441 P SG 12.69.370 11.931.320 788.050 768.050
1442 88 90.54.979 85.067.936 5.476.044 5.476.04
144
144 33 Ac EI Equt144P SG 5.102.415 4.793.824 30.591 30.591
144 P SG 3.96.930 3.72.891 240.038 240,0
, .1447 P SG 30.647.338 28.793.806 1.85.532 1.853.532
144 P SG 3.423.22 3.216.188 207.034 207.34
1449 B8 43.141.905 40.532.709 2.609.196 2.60.196
145
REVSED PROTOCOL Page 2.23 Yea
FERC BUS UNUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTENT ADJTOTAL
1451
1452
145 33 Mi. Po_r Plant Equipent
145 P SG 1.371.505 1.288.558 82.94 82.948
145 P SG 197,885 185.917 11.96 11.968
145 P SG 982.272 922.865 59.407 59.407
1457 P SG 12.963 12.179 784 784
1458 B8 2.56.625 2.40.518 155.107 155.107
145
146 336 Roa. Raads & Bris
1481 P SG 4.63.94 4.356.505 280.44 280.44
1462 P SG 828.976 778,84 50.136 50.136
146 P SG 7,882.825 7.40.077 476.748 476.748
146 P SG 592.158 556.34 35,813 35.813
146 B8 13.94.904 13,097.767 84.137 843.137
148
1467 337 Hy Plt ARO
148 P 5
1469 B8
1470
1471.HP Ur Hy Pla . Ac 30
1472 P 5
1473 P SG
1474 P SG
1475 P SG.
1476 B8
1477
1478 Totl Hyraulic Prolln Plant B8 533,774,338 501,491,998 32,282,34 1,538,527 33.820.867
1479148 Su of Hyraul Pl by Facto
1481 5
148 SG 53.774.338 501,491.998 32,282.34 1.53,527 33.8.867
148 DG
148 DGU .....
148 Toc Hv Plt by Fac 533.774.338 501.491.998 32.282.34 i.38.527 33.820.867
148
1487 34 La an La Rig
148 P SG 21.54,670 20,239,783 1.302.887 1.302,887
1489 P SG
1490 P SSGCT .
1491 B8 21,542.670 20.239.783 1.302.887 1.302.887
149
149 341 Sts an Imprents
1494 P SG 108,044.808 101,510.325 6.534.483 .6.534.483
1495 P SG 170,926 160.588 10.337 10.337
1496 P SSGCT 4.237.997 3,977.344 260.654 26.654
1497 B8 112,453..730 105.64.257 6.805,474 6.805.474
1498
149 34 Fuel Ho Pr & Acsss
150 P SG 6,597,35 6.198.352 39.004 39.004
1501 P SG 121.33 114.00 7.339 7.339
1502 P SSGCT 2.257.625 2.118,772 138.853 138.853
150 B8 8,976.320 8.431.124 545.195 545,195
150
150 343 Pri Mo
150 P S
1507 P SG 774.173 727.351 46.821 46.821
150 P SG 83.146.070 788.395.038 50.751.032 38.123.174 88.874.206
150 P SST 51.399.802 46.238.511 3,161.291 (65.257)3,0.034
1510 B8 891.320.04 837.36.900 53.959.145 38.57.917 92.017.062
1511
1512.34 Getor
1513 P S
1514 P SG
1515 P SG 207,48.517 194,93.982 12,54.534 12.54.534
1516 P SSGCT 15.873,643 14.897.352 976.292 976.292
1517 B8 22.358.160 209.833.334 13,524.826 13,524,826
REVISED PROTOCOL.Pag 2.24
Yea-End
FERC BUS UNADJUSTED RESUl. TS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAl OTHER IDAHO ADJUSTMENT ADJTOTAl.
1518
1519 345 Accssory Electric Plant
152 P SG 112.644,196 105,831.54 6,812.651 6,812.651
1521 P SG 156,586 147.116 9,470 9.470
1522 P SST 3.072,971 2.883.971 189.00 189.000
1523 B8 115.873,754 108.862.633 7.011,121 7.011,121
1524
1525
1526
1527 34 MI. Pow Plt Equipment
1528 P SG 6.65.073 6.250.699 402.374 402,374
1529 P SG 11.813 11.099 714 714
153 B8 6.66.88 6.261.798 403.088 403.088
1531
1532 347 Ot Proucio ARO
153 P S
1534 B8
1535
1536 OP Unlasifed Oter Prod P1ant-Acc 300
1537 P S
153 P SG
1539
1540
1541 Totl Otr ProductIon Plant B8 1.380,189,56 1,29,637.827 83.551,737 38,057,917 121.609,654
1542
1543 Summary of Other Prouclion Plant by Factor
154 S
1545 DGU
1546 SG 1.303.347.52 '1.224.521.879 78.825.647 38,123.174 116.94.821
1547 SSGCT 76,842.039 72.115.949 4.726.090 ~65.257)4.660.833
154 Tota of Otr Prctn Plan by Factor 1.380.189.564 1.29.637.827 83.551.737 38. 57.917 121.609.654
1549
1550 Exrital Pla
1551 103 Expemental Plant
1552 P SG
1553 Totl Experienl Proucton Plant 88
155155 Total Prouction Plant 88 6,774,281,873 6.365.723,063 408,558,809 51,408,46 459,967,273
1556 350 La an Land Rights
1557 T SG 21.205.197 19,922.720 1,282,477 1,22.477
1558 T SG 48.627.811 45.68,831 2.94,960 2.94,960
1559 T SG 23.515.907 22.093.660 1,422.227 (63,234)1,358.994
1560 B8 93.348,915 87.703,231 5.645.684 (63.234)5.582,451
1561
1562 352 Strures and Imprents
1563 T S
1564 T SG 7,679.83 .7.215,359 46.471 46.471
1565 T SG 18.276,825 17.171.45 1,105.371 1,105.371
156 T SG 37.781.28 35.49,431 2.284.997 2.28.997
1567 B8 63.738.084 59.883.244 3.854.840 3.85.84
1568
1569 353 Stti Equint
1570 T SG 134,220.44 126.102,876 8,117.58 8.117,569
1571 T SG 195.779.604 183.938.975 11,840,629 11.840,62
1572 T SG 69.655.578 654.522,282 42.133.296 42.133,296
1573 B8 1.026.655.627 964.564,133 62.091.93 62,091,493
1574
1575 35 Towers an Fixs
1576 T SG 156.34.058 146.884.709 9.45.349 9,45.34
1577 T SG 126.993.44 119.312,959 7,68.48 7.660.484
1578 T SG 141,302.906 132,756.994 8.545,912 8.545,912
1579 B8 424.636.408 39,954,662 25,681.746 25.681,746
1580
1581 35 Pos and Fixs
1582 T SG 68,63.597 64,48.498 4.151.09 4,151.09
158 T SG 118.39.485 111.23.121 7.160.364 7.160.36
1584 T SG 341,601.20 320.941.376 20.659.828 4.928,802 25.588.630
1585 88 528,631.286 496.659.995 31.971.291 4.928.802 36.900.093
156
REVED PROTOCOL Page 2.25
y...End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR R.f TOTAl OTHER IDAH ADUSTMENT ADJTOTAL
1587 356 Clanng and Gring
1588 T SG 207.525.185 194.974.191 12.55.99 12.550.99
1589 T SG 158.557.353 148.967.903 9.589.45 9.589.45
1590 T SG 330.381.583 310.40.311 19.981.273 19.981.273
1591 B8 696.464.121 654.342.404 42.121.717 42.121.717
159Z
1593 357 Undrgnd Coui
1594 T SG 6.371 5.98 385 385
159 T SG 162.746 152.90 9.843 9.84
159 T SG 3.108.495 2.920.495 188.00 188.00
1597 B8 3.277.612 3,79.384 198.228 196.228
1598
1599 35 Unrgro Coors
160 T SG
1601 T SG 1.018.66 957.055 . 61.608 61.608
1602 T SG 6.34.85 5.96.99 383.854 38.854
1603 98 7.36.512 6.920.051 44.462 44.462
1604
160 35 Roa an Trails
1606 T SG 1.890.428 1.776.096 114.332 114.332
1607 T SG 49.754 46.832 29.922 29.922
160 T SG 9.087.04 8.537.46 549.579 54.579
1609 98 11.472.227 10.778.394 693.833 693.833
1610
1611 TP Un Tra Pla . Act 300
1612 T SG 21.93.847 20.60.483 1.326.364 1.326.364
1613 B8 21.930.847 20.604.483 1.326.364 1.326.364
1614
1615 TOO Unssd Tras Su Plant. Acc 30
1616 T SG
.1617 B8
1618
1619 Total Transmiion Plant B8 2,87,520,64 2,703,489,982 174,030,658 4.865.568 178,896.225
162 Suar of Trasm Pla by Faç
1621 DGP
1622 DGU
162 SG 2.877.52.64 2.703.489.982 174.030.658 4.865.68 178.896.225
1624 Tot Tramisio Pl by Faç 2.877.520.640 2.703.489.982 174.030.658 4.865.568 176.696.225
1625 36 Lan and Lan Right
1626 DP S 45.675.442 44.418.22 1.257.219 1.257.219
1627 B8 45.675.442 44,418.223 1.257.219 1.257.219
1628
162 361 Str an tmpiment
163 DP S 51.310.36 50.502.370 807.99 807.99
1631 B8 51.310.36 50.502.370 807.990 8õ7.990
1632
163 362 Stn Equt
1634 DPW S 683.432.277 657.449.397 25.982.880 25.982.880
1635 B8 68.432.277 657.44.397 25.982.880 25.982.880
1636
1637 363 Sto Ba Equen
1638 DP S 1.457.805 1.457.805
1639 B8 1.457.805 1.457.805
164
1641 36 Pols, Tow & Fixt
1642 OPW S 83.589.385 781.879.85 54.909.535 54.909.535
164 B8 83,58.385 781.679.850 54.909.535 54.909.535
164
184 365 Ovad Con(lor
164 OPW S 803.34.307 570.596.981 32.746.326 32.746.326
1647 B8 603.343.307 570.596.981 32.746.326 32.746.326
164
REVseD PROTOCOL Pag 2.26
Vea-end
FERC BUS UNADUSTED ReSULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUS1MENT ADJTOTAL
1649 36 Undrground Conduit
1650 DPW S 267.66.461 26.916.997 6.747.46 6.747,464
1651 B8 267.664,461 260.916.997 6.747.46 6.747,464
1652
165
165
165
165 367 Unrgun Cond
1657 DPW S 642.487,853 620,397.210 22.09.64 22.09.643
1658 B8 642.487.853 620.397.210 22,090.643 22.09,643
1659
166 368 Lin Trasfrmers
1661 DPW S 96.35.257 902.743.891 60.612.365 60.612.35
1662 B8 963.356.257 902.743,891 60.612.365 60.612.365
166
166 369 Ses
166 DPW S 503.373.333 478.582.329 24.791.003 24.791,003
1666 B8 503,373.333 478.582.329 24.791.03 24.791.003
1667
166 370 Meter
166 DP S 184.224.195 170.48.80 13.735.388 13.735.388
1670 B8 184.224.195 170,48.808 13.735.388 13.735.388
1671
1672 371 Insllns on Customers' Prmiss
1673 DPW S 8.86.604 8.700.244 160,360 160.36
1674 B8 8.860.604 8,700.244 160.360 160.360
1675
1676 372 Lea Pr
1677 DPW S 49.658 44.785 4.873 4.873
1678 B8 49.65 44.785 4,873 4.873
1679
166 373 Str Lig
1681 DP S . 59.329.69 58.742,967 58.732 58.732
168 B8 59.329.699 58.742,967 586.732 586.732
1683
1684 DP Unssed Di Pl . Ac 30
168 DPW S 33.108.283 31,161.289 1.946.994 1.94.99
1686 B8 33.108.283 31.161.289 1.946.994 1.946.994
1687
1688 DS Uncla Di Sub Plant - Ac 300
1689 DP S
1690 B8
1691
1692169 Tot DItribution Plant BS 4,88,262,918 4,637,883,146 246,379,772 24,379.772
1694
169 Sumary of Di Plnt by Fac
1696 S 4.88262,918 4.637,883.146 246,379.772 246.379.772
1697
169 Total Dislr Pla by Fact 4.884.262.918 4.637.883.146 246,379.712 246.379.712
REVED PROTOCOL Pag 2.27
Yea-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADTOTAL
1699 389 Land an Land Rights
1700 GoolTUS 5 8.55.822 8.358.183 197.639 197.639
1701 CUST CN 1.128.50 1.082.64 45,860 45.86
1702 PT 5G 332 312 20 20
1703 GooG 5G 1.228 1.153 74 74
1704 PTO 50 5.598.055 5.275.859 322.196 322.196
1705 88 15.283.942 14.718.154 565.789 565.789
1706
1707 39 Sts an Imprvem
1708 G-TUS 5 104.99.183 95.169.127 9.821.058 9.821,05
1709 PT 5G 358.127 336.46 21.659 21.659
1710 PT 5G 1.573.572 1,478.404 95.169 95.169
1711 CUST CN 12.05.26 11.56.327 489.937 489.937
1712 G-5G 4.061.516 3.815.878 245.63 245.63
1713 PT 50 103.687.865 97.720.113 5.967.752 5.967,752
1714 B8 226.727.527 210.086.317 16.641.211 16,641.211
1715
1716 391 0f Furre & Equent
1717 G-US 5 14.820.180 13.881.914 938.266 93.26
1718 PT 5G 277.657 260.86 16.793 16,793
1719 PT 5G 281.018 264.022 16.99 16.99
172 CUST CN 6.30.109 6.49.84 256.265 25,25
1721 G-SG 4.88.96 4.587.64 29.319 29.319
1722 P SE 172.221 160.878 11.34 11.34
1723 PT 50 69.168.973 65.187.95 3.981.018 3.981.018
1724 G-SSGCH 225.27 212.131 12.897 12,87
1725 G-SSGCT 13.46 12.63 828 828
1726 B8 96.147,619 90.617.895 5.529,724 5.529.724
1727
1728 392 Trapon Eqent
1729 G-TUS S 69.741.80 64.957.84 4.783.95 4.783.95
173 PTD 50 8.313.30 7.83.832 478,472 418.472
1731 G-G 5G 14.98.837 14.078.376 90.262 90.262
1732 CUT CN
1733 PT 5G 1.00.011 947.047 60.964 60.96
173 P 5E 752,743 703.164 49.579 49.519
173 PT 5G 155.978 146.54 9.433 9.43
113 G-SSGCH 359.6Ð 33.99 20.610 20.610
1737 PT 5SGCT.44.65 41.909 2.746 2,746
1738 B8 95.360.737 89.048.716 6.312.021 6.12.021
1739
1740 393 Stos Equnt
1741 G-TU 5 8.914.812 8.278.705 636.101 636107
1742 PT SG 33.531 315.23 20.293 20.29
1743 PT 5G 673.39 632.672 40.727 40.727
1744 PTO 50 49.538 46.075 28.463 28.46
1745 G-G SG 2.928.00 2.750.919 177.084 177.08
1746 PT SST 106.99 100.413 6.581 6.581
1747 B8 13.45.276 12.544,022 909.254 90.254
REVISED PROTOCOL Pag2.2S
Vear-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADJTOTAL
1748
1749 39 Tools. Sh & Garge Equipment
1750 G-ITUS S 31.213.775 29.592.373 1.621,402 1.621,402
1751 PT SG 2.809.419 2.639.507 169.912 169.912
1752 G-G SG 18.089.337 16.99.305 1.094.032 1.094.032
1753 PTO SO 4.130.587 3.892.851 237.736 237,736
1754 P SE 7.106 6.638 46 46
1155 PT SG 4.318.672 4.057.482 261.191 261,191
1758 G-G SSGCH 1.798,459 1.695.386 103.073 103,073
1757 G-5G SSGCT 74.831 70.229 4.602 4,602
1758 B8 62.442,187 58.949.771 3.492,416 3.492.416
1759
1760 39 Labto Eqpment
1761 G-ITUS S 27,85.613 26.316.59 1.343.554 1.34.5
1762 PT SG 60.181 58.541 3.640 3.64
1763 PT SG 827.868 777.799 50.069 50,06
1764 PTO SO 5.474.08 5.159.027 315.061 315.061
1765 P SE 42.43 39,64 2.795 2.795
1766 G-SG 5.746.607 5,399.05 347,551 347.551
1767 G-5G SSCH 253.001 238.501 14.500 14,5
1768 G-G SSCT 110.119 103.34 6.773 6.773
1769 B8 40.173.914 38.89.972 2,063.943 2.083.943
1770
1771 39 Powr Opra Equen
1712 G-5TUS S 89,728.297 83.140.656 6,587.641 6.587.641
1773 PT SG 981.699 922.327 59.373 59.373
1774 G-5G SG 27.006.474 25.373.139 1.633.335 1.63.33
1775 PTO SO 1.676,426 1.579.94 96.487 96.487
1776 PT SG 2.088.71 1.962.349 126.322 126.322
1777 P se 73.823 68.961 4.862 4.862
1778 P SSGCT
1779 G-SSH 724,64 68.117 41.531 41.531
1780 B8 122.280.37 113.730.488 8.549.549 8,49.549
1781 397 Comun Equipen
1782 CO_EO S 106.217.120 100,038.244 . 6.178.876 6.178.76
1783 COM_EO SG 5.569.387 5.232.554 336.83 336,33
1784 COM_EO SG 10.751.58 10.101.336 650.249 65.249
1785 CO_EO SO 49.796.807 46.930.753 2.866.054 288,847 3.154.901
1786 COM_EO CN 4.520.306 4.336.612 183,94 183.694
1187 COM_EO SG 62.831.44 59.031,437 3.80.007 3,80.007
1188 COM_EO SE 113,108 105.658 7.450 7,50
1789 COM_EO SSGCH 952.959 898.34 54.616 54.616
179 COM_EO SST 87.578 82.192 5.386 5.386
1791 B8 240.840.294 226.757.129 14.083.164 288.847 14.372.011
1792
1793 39 Mi. Eqen
1794 G-ITUS S 1,144,675 1.083.959 60.716 60.716
1795 PT SG 18.689 17.559 1.130 1.130
1796 PT SG 25.819 24.258 1.562 1.56
1797 CUST CN 197.26 189.244 8.016 8.016
179 PTO SO 3,2,731 3.22 168 184.56 184,563
1199 P SE 3.531 3.299 23 23
1800 G-G SG 1.313.737 1.234.283 79.45 79.454
1801 G-G SSGCT 2.65 2.487 163 163
1802 B8 5.913.093 5,577.256 335.837 335.837
1803
1804 39 Co MI
1805 P se 262.931.40 245.613.524 17.317.881 11.482.753 28.8.634
180 MP P SE
1807 B8 262.931,404 245.613.524 17.317.881 11.482.753 28.800.634
180
180 39L WI Ca Lease
1810 P SE B8
1811
1812
1813 Rem Cata Lea
1814 B8
1815
REVSED PROTOCOL Page 2.29
VearoEnd
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1816 101139 Genral Caitl Leases
1817 G-TU5 5 7.306.30 7.306.30
1818 P 5G 12,411,745 11.661.090 750,655 750.655
1819 PTO 50 12.902.451 12.159,851 742.600 742.60
1820 B9 32.620.226 31.126.971 1.493.255 1,493.25
1821
1822 Remove Ca Leases (32.620.226)(31.126.971)(1,493.255)(1.493.255)
1823
1824
1825 101134 Ge Gas Lin Ca Leas
.1826 P 5G
1827 B9
1828
182 Remove Ca Leass
183
1831
1832 GP Unass Ge Plant. Acc 30
1833 G-ITUS 5
183 PTD 50 692.740 652.869 39.871 39,871
183 CUST CN
1836 G-G 5G
1837 PT 5G
183 PT 5G
1839 B8 692.740 652.869 39,871 39.871
1840
1841 399G Uncsi Gen Plant. Acc 30
1842 G-ITU5 5
1843 PTD SO
184 G-5G
184 PT 5G
1846 PT SG
1841 B8
1848
1849 Tot Gene Plant 88 1,182.246.771 1.106.386.112 75,860,659 11,171,600 87,632.259
185
1851 SUar of Gene PI by Fac
1852 5 470.292.30 43.123.098 32.169,211 32.1..211
185 DGP
185 DGU
185 5G 186,373.310 175,101,56 11.271.742 11.211,142
185 SO 265.142.565 249.882,293 15.260.272 288.847 15.549.119
1857 5E 284.09,376 246.701.765 17.394,611 11.482.753 28.877384
1858 CN 24.208.44 23,224.673 983.772 98772
1859 .DEU
186 SST 27.080 27.08
1861 SS 247.226 247,226
186 Less Ca Lea 1,493.255)1.493,255)
1863 Tota Gene Pla by Facr
186 301 Orzati
1865 i.ITU5 5
186 PTD 50
1867 i.G 5G
186 B8
1869 302 Fra & Cose
1870 i.ITU5 5 1.00.00 1.000.00 1,00.00
1871 i.G 5G 2.94.25 2.767.129 178.127 178.27
1872 i.G 5G 60,589.96 56.925.517 3.66.44 2.56.008 6.230.451
1873 i.G 5G 9.240.742 8.681.867 558.874 55.874
1874 P 5G
1875 P 5G 60.993 56.64 36,348 36.348
1876 B8 74.376.951 68.939.158 5.437.792 2.566,008 8,003.800
1877
REVSED PROTOCOL Page 2.30
Vear-End
FERC BUS UNADUSTD RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
1878 303 Miscllanou Intangibl Plant
1879 1-SITUS S 1.537.927 1.145.54 392.381 392.381
188 I-SG SG 63.40.863 59.228.190 3.812.672 3.12.672
1881 PTO SO 378.024.43 356.267.250 21.757.184 21.757.184
1882 P SE 3,00.044 3.362.929 237.116 237.116
1883 CUST eN 108.710.99 104.293.246 4.417.750 4.417.750
1884 P SG 34.575 323.736 20.84 20.840
1885 P SSGCT
188 88 555.258.839 524.62.897 30.637,942 30.637,942
1887 303 Less Non-Ut Plant
188 1-SITUS S
188 555.258.839 524.620.897 3õ.637.942 30.637.942
1890 IP Unclassi Intaibl Pla - Ac 30
1891 1-SITUS S
1892 I-SG SG
189 P SG
189 PTO SO
1895
1896
1897 Tot Intangible Plant B8 629,635,79 593,56,055 36,075,735 2,56,008 38,641,743
1898
1899 Suar of Intng Plnt by Fac
190 S 2.537.927 1.145.54 1.39.381 1,32,81
1901 DGP .'-
190 OGU
190 SG 138.762.389 128.491.08 8.271.30 2.56.00 10.837.312
1904 SO 378.024.435 356.267.25 21,757.184 21.757.184
190 CN 108.710.99 104.23.246 4.417.750 4.417.750
190 SSCT
1907 SSCH
1908 SE 3.600.044 3.36.929 237.116 -237.116
190 T otlntibi Plt by Facto 629.635.790 59.56.055 36.075.735 2.566.008 38.41.743
1910 Summary of Unssid Plnt (Accun 1 (6)
1911 OP 33.106.283 31.161.289 1.94.99 1.946.994
1912 . DSO
1913 GP 692.740 852.86 39.871 39.171
1914 HP
1915 NP
1916 OP
1917 TP 21.93.847 20.604.483 1.326.36 1.32,3
1918 T50
1919 IP
1920 MP
1921 SP 526.307 494.476 31.831 31.831
1922 Tote Unss Pl by Facto 56.258.176 52.913.11 3.34.059 j.34.059
1923
1924 Tot Ele Plant In service B8 16,347,947,992 15,407,04,359 94,905,633 70,611,639 1,011,517,272
REVSED PROTOCOL Page 2.31
V_oEnd
FERC BUS UNADUSTD RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
192 Summary of Elec Plt by Facor
1926 S 5.357.093.153 5.071.151,790 279.941.364 279.941,36
1927 SE 267.69.421 25.06.694 17.631.727 11.482.753 29.114.48
1928 DGU
1929 DGP
193 SG 9,511.594.911 8.93.339.570 575.255.341 48.424.592 623,679.93
1931 SO 64.167,00 606.149.543 37.017,456 288.847 37,306,303
1932 CN 132.919,44 127.517,918 5.401,522 5.401.522
193 DEU
193 SSCH 390,814.961 368.416.65 22.398.30 10.48,704 32.879.012
1935.SSCT 71.282.332 72,529.163 4.753,170 (65.257)4,687.913
1936 Less Ca Leases ~32.62O.22)~,.126.971)£.493,255)l,.493.255)1937 16. 47.947.992 15, 7.042.359 9 .905.633 70,611.639 1.0 1,517.272
193 105 Plan He For Futre Use
193 DPW S 50.024 50.024
194 P SG
1941 T SG 12.239.128 11.49.913 740,215 (740.215)0
1942 P SG
1943 P SE 953.014 89.244 62.710 (62,710)(0)
194 G SG
194
1948
1947 Tot Plan He For Fure Use 810 13,697.167 12.89.182 802.985 (80.985)0
194
1949 114 Ele Pl Ac Adjts
195 P S
1951 P SG 142,633.069 134,00.710 8,626.359 8.626.359
195 P SG 14,56.711 13.680.088 880.623 88,623
195 Tot Elec Plant Acquision Adjustment 815 157,193.780 147.686.798 9,506.982 9.506,982
195
1955 115 Accum Pro fo Asset Ac Adjtm
195 P S
1957 p.SG (74.485.702)(69.962.06)(4.503.639)(4,53.63)
195 P SG
1'0.902.48)1'0.243,09' l
(659.374)(659.374)
1959 815 85.368,167)80.205.153 (5,163.014)(5.163.014)
196
1961 120 Nu Fue
1962 P SE
196 Total Nulear Fue 815
196
196 124 Weat
1966 DM S 4.417,918 4.378.819 39.09 39.09
1967 DMC SO l2.48)
~2.321)(142)(142)
196 B16 4,45.45 4.:H.49 38.957 3U57
1969
1970 182W Weath
1971 DMSC S 6,475.025 921.54 5.553.48 5.5.48
1972 DMSC SG
1973 DM SGCT
1914 DMSC SO ....
1975 816 6.475.025 921.54 5,553.48 5.553,480
1976
1977 186W Wøa
1978 DMSC S
1979 DMC CN
1980 DMC CNP
1981 DMSC SG
1982 DMC SO
1983 816
1984
196 Tot Weaterzaio 816 10.890.479 5,29.042 5,592,437 5.592.437
REVSED PROTOCOL Page 2.32
Yea-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
198
1987 151 Fuel St
198 P DEU
1989 P SE 93.079.685 86.94.026 6.130,659 99.919 7,127,578
199 P SSECT
1991 P SSECH 5.254.497 4.934.54 319,952 172.157 492.109
1992 Tot Fuel Stock B13 98,334,182 91,883,570 6,450,611 1,169,075 7,619,687
1993
1994 152 Fuel St . Undisbued
199 P SE
1996
1997
1998 2516 DG& T Worin Capi Desit
199 P SE (551,00)(514.70)(36.291)(36.291)20 813 (551.00)(514.709)(36.291)(36,291)
201
202 2517 oo&T Workng Cap Deposit20PSE (1.54.144)(1.442,44)(101.704)(101.704)
204 813 (1.544.144)(1,442.44)(101.704)(101.704)
20020 25319 Provo Working Cal Deposit
2007 P SE
200820
2010 Total Fue Stok 813 96.239.038 89,926.422 6.312.616 1.169.075 7,481.91
2011 154 Maters and Supplies
2012 MSS S 75,379.082 70.917.669 4.461.413 4.461,413
2013 MSS SG 1.807.015 1.697,727 109,287 109.287
2014 MSS SE 4.314,408 4,030.241 284,167 284,167
2015 MS SO 194,683 183.478 11,25 11,25
2016 MSS SNPPS 73.226.690 66.614.204 4.412.46 4.412.46
2017 MSS SNPPH (21.081)(19,80)(1.275)(1.275)
2018 MSS SNPD (4.850.776)(4.623.640)(227.136)(22.136)
2019 MSS SNPT
2020 MS SG
2021 MS SG
2022 MSS SSGCT
2023 MSS SNPP
2024 MS SSGCH
2025 Total Materials and Supplies 813 150,050,022 140,999,873 9,050,148 9,050,148
2026
2027 163 Stres Exnse Undstruted
2028 MSS SO
2029
2030 813
2031
2032 2516 Pro Worin Capi Deposit20MSSSNPPS (273.00)(256,55)(16.45)(16,45)20
205 813 (273.00)(256.550)(16.45)(16.45)
2036
2037 Tot Mate & Sues B13 149.777.022 140.743.324 9.033.698 9.033,698
2036
2039 165 Prepayments
2040 DMS S 3.232.469 3.56.96 173,502 173,502
201 GP GPS 8.147.933 7.678.979 468,95 ..95
2042 PT SG 5.054.50 4,748.813 30,69 30.69320PSE3.641.35 3,401,516 239,83 239.36
2044 PTD SO 19.22.698 18.114.452 1.106.247 1.106.247
2045 Totl Prepayments 815 39,296.959 37,002,726 2,294,233 2,294.233
20
REVSED PROTOC Page 2.33
Year-End
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAl
207 182M MI Regulato Assets
204 0052 5 58.43.687 58.721.817 (287.130)(28.865)(315.995)
209 DEFSG SG 7.092.836 6.66.866 428.970 428.970
2050 P SGCl 10.758.573 10.103.447 653.126 65.126
2051 DEFSG SG.p (68.181)(68.181)
2052 P SE
203 P SSGCT20002SO 7.055.54 6.649.462 406,82 406,8220B1183.339,641 82.138.593 1.201.048 (97,046)1,104,002
206201 186M MI Deer Dets20LABOR 5 4.22.084 4.220.084
209 P SG20PSG
2061 DEFSG SG 39.49.83 37.102.453 2.388.381 2.368.381
202 LABOR SO 97.769 92.142 5.627 5,627
203 P SE 6.030.427 5.633,235 397.192 142.349 539.541
20 P SNPPS
205 GP EXeTAX .20 Totl Mis. Defe Debi 811 49,839,114 47,047,914 2,791.200 142,349 2,933.549
207
2068 Working Ca20ewcCah Woin Cait
2070 ewe 5 44.40.697 42.132.034 2.274.663 1,232.84 3.507,507
2071 ewe SO
2072 ewe SE
2073 B14 44.406.697 42.132.034 2.274.663 1.232.844 3.507.507
2074
2075 owe Ol Wo ca.
2076 131 c.GP SNP 22.99.473 21.703,480 1.295.993 (1.295.993)
2077 135 WO Fii GP SG 2.691 2.528 163 163
2078 141 __GP SO 918.46 86.598 52.862 52.862
2079 143 OlAJ GP SO 16.07.23 15.651.401 955.829 955.829
20 232 Al PTO 5
2081 23 Al PTO 50 (1.278.895)(1.205.288)(73.607)(73,607)
2082 232 Al P SE (1.216.083)(1.135.98)(80,097)(80.097)
203 232 Al T 5G 2 2 0 0
208 2533 0l"' li CN. P 5
205 253 _-'ll.CN.P SE (5.60.322)(5.236.130)(36.192)(36.192)20 23 -_.IlP SE (2.401.44)(2.243.273)(158.170)(158.170)
207 230 -_.IlP 5
208 25105 ARRoLl P 5 (30.363)(30.363)
209 25105 ARRoLIo P SE (437,40)(40.596)(28.810)(28.810)20 2533 ~_P SSECH
2091 B14 29,558.34 27.96.372 1.594.971 (1.295.993)298.978
20220 Totl Wong Capil B14 73,96,040 10,095,406 3,869,634 (63,149)3,806,48
2094 MiHane Rate Ba2018221Unr Pl & Reg Stud Co
2096 P 5
20720 B15
2099
2100 182 Nur Pl . Troja
2101 P 5 (1.059.80)(1,059.80)
2102 P TROJP 2.519.600 2.365,155 154.44 15444
2103.P TROJ 3.689.386 3.462.703 226.683 226.683
2104 815 5.149.186 4.768.058 381.128 381,128
2105
2106
REVISED PROTOCOL Page 2.34
Yea-Ed
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADJTOTAL
2101
2108 1869 Mis Derr DebiTrojan
2109 P 5
2110 P 5NPPN
2111 615
2112
2113 Totl Micellaneous Rat Base B15 5,49,186 4,768,058 381,128 381,128
2114
2115 Total Rat Base Additons B15 59019.257 55,396,311 36.622,94 34,244 36,971,190
2116 235 Custer Servic Depoit
2111 CU5T 5
2118 CU5T CN
2119 Tot Customer Serve Deposit B15
2120
2121 2281 Pr Ins PTD 50
2122 222 Inj & Dam PTD 50 (6.054.192)(5.705,743)(34.44)(34.449)
2123 2283 Pen & Ben PTD 50 (20,38,156)(19,213.397)(1,113,359)(1.173,35)
2124 25 RegLiab PTD 5G (52,919)(52.919)
2125 25 RegLia PTD 5E (101.06)(101.08)
2126 25 Ins Pro PTD 50 ..-.-
2121 615 (26.44.948)(24,919,140)(1.521.808)(153.987)(1.675.795)
2128
2129 22 Aceu Hy Relnsi Obligation
2130 P 5
2131 P 5G
2132 815
2133
2134 22842 Prv-Tro P TROJO (2,48,00)(2.331.387)(152.622)(152.622)
2135 230 ARO P TROJP (2.273,192)(2,134,414)(139.318)(139,378)
2138 25105 ARO P TROJP (86.813)(812.741)(53.072)(53.072)
2137 25 P 5 251.99 251.99 .-
2138 615 (5.371.617 .(5.026.54)(345,02)(345.072)
2139
2140 252 Cu Adncs fo Con
2141 DPW 5 (17,214.23)(11.164.55). (49.619)(126.145)(175,24)
2142 OPW 5E
2143 T 5G (3.5.873)(3.32.54)(214,331)(109.501)(3232)
2144 DPW 50
2145 CUST CN 3.212.311 3.139.33 132.919
1132,919)
0
2146 Totl Cusomer Adanc fo Constrction 819 (17,485,789)(17,354,757)(131,031)36,625)Ø..656)
2147
2146 25 502 Emsis
2149 P 5E 12.68.5411
g,68,541I
2150 819 2.682.54l .682.541
2151
2152 25 0I De Cn .
2153 P 5 (4,993.83)(4.917.886)(75.95)(7.95)
2154 LAR 50 (532,374)(501.13)(30,641)(86.622)(915,2)
2155 P 5G (19.09,719)(11.93.882)(1.154.837)(86,57)(1.241.424)
2156 P 5E ¥.132.1871 ~,552.2331 (179.551 (119.95!
2157 819 ( 7.35.120 ( .911.734 (1.441.386 (971.210)(2.412.595
REVSED PRTOCOL Page 2.35
Year-End
FERC BUS UNADUSTD RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH .ADUSTMENT ADTOTAL
2158
2159 190 Acmul Defem Incme Taxes
2160 P S 8,073,135 7.567.003 506.132 (175.772)330,36
2161 CUST CN 112.198 107,638 4,559 (96)3,592
2162 P IBT 22.268 22.268
2163 LAOR SO 40,281,86 37,96.44 2.318,421 1,476,05 3,794.476
2164 P DGP 36 36
21~CUST BABT 2,839.496 2.737,051 102.44 (68.094)34.351
2166 P TROJO 137 128 8 (901)(892)
2167 P SG 42.278,827 39.721,82 2.55.997 262,489 2.819.48
2168 P SE 17.356.183 16,213.025 1.143.159 991.363 2.140.52
2169 PTO 5NP (0)(0)(0)(1,201)(1.201)
2170 DPW 5NPO 767,198 731.275 35.924.806 36.130
2111 P 55GCT 2.50.335.2.351,241 154.088 154,088 30.116
2172 Tot Acum Deed In Tax"819 114,214,140 107.393.006 6,821,134 2.66,133 9.487.881
2173
2174 281 Acc Deferr Inco Taxes
2175 P 5
2176 PT OGP
2177 .T 5NPT
2178 B19
2179
2180 28 Accul Defeln Tax
2181 GP 5 (4.587.219)(4.078.150)(50.069)(83.432.38)(83.941.44)
2182 ACCT OITBAL (1,307,96.45)( 1.2,104,997)(81.878.45)79.277.22 (2.601.11)
2183 PT GP5 (58)(58)
2164 LABOR 50 (14,601.54)(13,761.151)(84.391)(148.691)(989,83)
2185 PT 5NP
2186 P 5E (13,070,44)(12.20.56)(860.88)(49,190)(910.70)
2187 P SG (12,819.089)(11,85.894)(163,195)(67.997)(831.192)
2188 B19 (1~352.861.155)(1,26,00.161 )(84,851,994)(4.421,034)(89.273,028)
2169
2190 283 Ac Defe In Taxes
2191 GP 5 (34.92.38)(34.179.121 )(750.262)698111 (52.151)
2192 P 5G (9,7l).40)(9,122.190)(581,219)94.807 (492.412)
2193 P 5E (16,716,219)(15.615.212)(1,101.008)130.483 (970.525)
2194 LAOR 50 (4.756.516)(4.482.755)(273.761)(36.547)(310.30)
2195 GP GP5 (14.06,082)(13,25.85)(809.228)30.594 (778.634)
2196 PTD 5NP (7.94.83)(7,49.212)(441.626)99.477 (348.149)
2197 P TROJO 180.050 168.98 11,06 35.737 46.799
2198 P .5SGCT
2199 P 5GCT (2,907.765)(2,731.20)(178.55)21.629 (151.927)
22 P SSCH
221 B19 (90,83.183)(86,706.56)(4.134.597)1.074.29 (3,06.301)
22223 Totl Acm De Incom Tax 819 (1,329,490.178)(1,247,325,321 )(82.164,857)(680,611)(82,845,468)
224 255 Acul Invtment Tax Cret22PT522PTDITC8 (2.90,86)(2,908.86)
2207 PTO ITC8 (4.401,706)(4.401,706)22 PTO ITC86 (1.973,007)(1.973.007)22 PT 1TC8 (281,502)(281.502)
2210 PTO ITC8 (604.58)(604.588)
2211 PTO ITC9 (373,45)(321,243)(52.215)10,228 (41.987)
2212 PTO IBT ...
00.073)
~3.131
2213 Tot Acml ITC 819 (10.543,126)(10.49.911 )(52.215).84)(î5.060
2214
2215 Tot Rae B_ Des
2216
RESED PROTOCOL Page 2.36
VearoEnd
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2217
. 2218
2219 108SP Steam Pro Plant Accumulted Depr
222 P S
2221 P SG (846,57.975)(794.888.915)(51.169.060)(51.169.06)
22 P SG (90a.37.747)(853.120.189)(54.917.558)(54.917.558)
2223 P SG (482.328.111 )(45 157.207)(29,170.904)(35.49)(29.20.394)
2224 P SSGCH (218.29.175)(20.788.57)(12,511.118)(158.314)(12.669.432)
2225 617 (2.45.723.008)(2.306.954.368)(147.768.640)(193,803)(147.962.443)
226
2227 108NP Nucr Pr Plant Accmulte De
2228 P SG
2229 P SG
2230 P SG
2231 617
2232
2233
2234 108 Hyic Pro Plt Ac De
2235 P S22PSG (142.234.272)(133.63.032)(8.602.240)(8,602.240)
227 P SG (28.034.185)(26.338.69)(1.95.49)(1.695,490)
2238 P SG (53207,003)(49,98.077)(3,217.926)(21.08)(3.2.012)
223 P SG (7.63.571)(7.172,837)(461.734)(16.093)(477.821)
2240 617 (231.110.031)(217.132.640)(13.977.391 )(37.179)(14.014,510)
2241
2242 1080P Ot Prucon Plant. Acc Depr
2243 P S
2244 P SG (1,911.321 )(1.79.726)(115.596)(115,59)
2245 P SG
2246 P SG
2247 P SSCT
2248 617
224922 108EP Expetal Plnt . Acc Depr
2251 P SG
2252 P SG22
225422 Totl Proucn Plant Accum DeprIation B17 2,791,088.453)2,622,960.435)168,128.018)1,505,904)169,633,921 )
2256
2257 Suma of Pro Pla Deciatn by Facto
2256 S
2259 DG22DGU
2261 SG (2.55.972.738)(2,402,328.618)(154.64.120)(1.35.201 )(155,94.321)
222 SSGH (218.299.175)(20.188.057)(12,511.118)(158.314.)(12.66.432)
226 SSGCT ~'5.8'6.54O)~'4.843.760)(972.780)2.611 (910.168)
224 Totl of Pro Pla Deatin by Fac (2.91.088.453)(2.22.960.435)(168.128.018)(1.505.904)(169.633,921 )
226522
2267 108TP Traision Pla Aculd Depr
226 T SG22TSG
2270 T SG
2211 Tot Trans Pl Accum Depreciatin B17
REVSED PROTOCOL Pag 2.37
Year-End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
227 108 Land an La Rights
2273 DP S (5.413.495)(5.186.980)(226.515)(226.515)
2274 B17 (5.13.49)(5.186.980)(226.515)(226.515)
2275
2276 10831 Sts an Imprvements
2277 DPW S (16.237.713)(15.697.823)(539.890)(539.890)
2278 B17 (16.237.71)(15.697.823)(539.890)(539.890)
2279228 108362 St Equent
2281 DP S (171.997.187)(164.377.105)(7.620.082)(7.620.082)
222 B17 (17.997.187)(164.377.105)(7.620.082)(7.620.82)
2283
2284 108363 Stra Batt Eqipment
2285 DP S (827.985)(827.98)
2286 B17 (827.985)(827.985)
227
2288 1084 Po. Tow & Fixs
229 DPW S (44.32.666)(418.184.425)(25.145.241 )(25.145.241 )
22 B17 (44.329.66)(418.184,425)(25.145.241 )(25.145.241 )
22122 10836 Ov Cors
2293 DP S (25.497.098)(238.49.864)(12.447.214)(12,447.214)
22 B17 (250.497.098)(238.049.884)(12,447.214)(12.447.214)
2222 1083 Un Condit227DPW S
t'12.289.079)
(108.994.948)(3.294.132)(3.29.132)
22 B17 (108.994.948)(3.294.132)(3.294.132)112.289.079)2223 108367 Unrg Couctor
2301 DPW S (231.621.244)(22.96.376)(10.654.868)(10.65.868)
2302 B17 (231.621.244)(220.96.376)(10.654.868)(10.654.868)
233
2304 108 Lin Traer
235 DPW S (357.08.811 )(329.931.490)(27.152.321 )(27.152.321)
2308 B17 (357.083.811 )(329.931.49)(27.152.321)(27.152.321)
237
238 108 Se23 DP S (150.691.618)(139,72.013)(10.919.606)(10.919.60)
2310 B17 (150.691.618)(139.772.013)(10.919.606)(10.919.606)
2311
2312 10870 Me
2313 DP S (7.56.631 )(71.94.570)(5.625.061 )(5.625.081)
2314 B17 (77.569.631)(71.94.570)(5.625,61 )(5.625.061 )
2315
2316
2317
2318 10871 Inta on Curs' Pieises
2319 DPW S (5.923.00)(5.784.615)(138.393)(138.393)
23 B17 (5.923.008)(5.784.615)(138.393)(138.393)
231
2322 10872 Lea Prrt
2323 DPW S (41.112)(38.426)(4.66)(4.66)
2324 B17 (41.112)(36.426)(4.686)(4.686)
2325
2326 108373 Str LIg
237 DP S 12.90.157)(20.632.456)(272.701)(272.701)
2328 B17 l2.905.157)(20.632.456)(272701)(272.701)
232923 10800 Un Dlst Plan - Ac 30
231 DPW S
232 8172323108DSUn Dit Sub Pl . Ac 30
2335 DPW S
2336 817
237
2336 108DP Unc Dlst Su Plt . Ac 30
2339 DPW S
234 B17
231
23223 Totl Distribution Plan Accum Depration B17 (1.84.427.806)(1,740.387.096)(104,040,710)(104,040,710)
23423 Sumary of DItrio Plan De by Facto23S (1.844.427.80)(1.740.387.096)(104.04.710)(104.04.710)
23723 Tot Ditrbution Deprti by Fac 817 (1.844.427.806)(1.740.387.096)(104.040.710)(104.04.710)
REVSED PROTOCOL Page 2.38
Vear-nd
FERC BUS UNAUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTENT ADTOTAL
2349 108P Gene Plant Accumulated Depr
2350 G-TUS 5 (148.928.702)(136.947.489)(11.981.213)(11.981.213)
2351 PT 5G (7,900.371 )(7.422.561)(4n.810) (477.810)
2352 PT 5G (15,35.85)( 14.424,327)(928,531)(928.531)
2353 G-5G SG (41.126,288)(38.63.99)(2.487.292)(2,487.292)
2354 CUST CN (6.170.38)(5.919.633)(250.749)(25749)23 PTD 50 (89.729.60)(84.56,216)(5.164,38)(20.433)(5.184,818)
2356 P 5E (487.172)(455.85)(32,087)(32.087)
2357 G-5G 55GCT (62.106)(58.286)(3.820)(3.820)
23 G-S 55GCH (2.571.626)(2.424.242)(147.385)(147.38)
235 B17 (312.329.106)(290.855.835)(21,473.272)(20.433)(~1.493. 705)
23
2361
232 10SMP Mining Plant Acmul Oepr.
236 P 5
2364 P 5E (158.684.619)(148.232.915)(10,451.704)(10.451.70)
238 B17 (158.68.619)(148.232.915)(10.451.704)(10.451.704)
236 108P Less Cea Sius Deeciatin
2367 P 5
236 B17 (158.684.619)(148.232.915)(10.451.704)l1.451.704)
2369
2370 108139 Acc Depr. Ca Lease
2371 PTO SO B17
2372
2373
2374 RØf Ca Leases
2375 B17
2376
2377 108139 Acum Depr. Caitl Leas
2378 P 5
2379 P SE B17
238
2381232 Remove Cap Leas23 B17
2384
235238 Tot Gel Plant Aceum Depreation B17 (471.013.725)(439.088.749)(31.924.976)(2,433)(31,945,410)
238723
2389
239 5umai of Genera Deiatin by Fac
2391 5 (148.928,702)(136.947.48)(11.981.213)(11.981.213)
2392 DGP
2393 DGU
2394 5E (159.171.791)(148.687.99)(10.48.792)(10,48.19)
2395 50 (89.729.60)(84.56.216)(5.184.384)(20.43)(5.184.818)
2396 CN (6.170.38)(5.919.633)(2,749)(25.749)
2397 SG (64.379.517 (60,485.88)(3.89.633)(3,893.63)
239 DEU
2399 5SGT (62.106)(58.28)(3.82)(3.82)
240 SSGCH (2.571.626)(2.424.242)(147,385)(147,3)
2401 Remov Ca Leases ..--
2402 Tota Gera Deciati by Fac (471.013.725)(43.08. 749)(31.924.976)(20.433)(31.945.410)
2403
240240 Tot Acum Depriatio. Plant In Seice B17 (8,184,56.183)(5,815.271.841)(389.292,542)(1.58,949)(370.880.490)
240 111SP Acum Prov fo Amrt-5eam
2407 P 5SGH
240 P SSGT
f623.695l f585.336l f38.36l f38.361240B18623.695 585.33 38.360 38.360
2410
2411
2412 111GP Accum Pro for Amort-Genra
2413 G-U5 S (17,04.932)(17.046.32)
2414 CUST CN (1.979,017)(1.898595)(80,422)(8.42)
2415 I-G SG (684.687)(64,278)(41.40)(41.40)
2416 PTO SO (6.72.243)(6.476.711 )(395.532)(395.32)
2417 P SE .--.
2418 818 (26.582.878)(26.065.515)(517,364)(517.364)
2419
REVSED PROTOCOL Page 2.39
V_oEnd
FERC BUS UNADJUSTED RESULTS IDHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADTOTAl
2420
2421 111HP Accm Prov for Am-Hro
2422 p SG (34.575)(323.736)(20.84)(20,.)
2423 p SG
2424 P SG (4.159)(3.907)(252)(252)
2425 P SG (311.1791 (292.36)(18.820)(18.20)
2426 618 (659.914 (62O.003ì (39.911)(39.911)
2427
2428
2429 1111P Accm Prov fo Amo.lntngie Plant
243 I-sTUS S (734.912)(39,679)(695.23)(695.23)
2431 P SG
2432 P SG (29.202).(281.106)(18.096)(1a.96)
243 p SE (859.911)(803.273)(56.638)(56.63)
243 I-S SG (31,441.49)(29.53.93)(1,901.562)(1.901.562)
243 I-SG (10.582.599)(9.942.570)(64.029)(76.372)(716.401)
243 I-G SG (2.491,687)(2.340.992)(150,696)(150.69)
2437 CUST CN (79.592.211 )(76.357,778)(3.23,43)(3.2.433)
243 P SSCT 38.36 38.80
243 p SSGCH (19,979)(18.834)(1.145)(1.145)
244 PTO SO (248.321.776)(234,029.624)(14.292.152)(14.29.152)
2441 618 (374.34.769)(353.353.785)(20.989.983)(38.012)(21.027.99)
2442 1111P less NonUlli Plnt
244 NUTIL OTH ....
244 (374.34. 769)(3s3.353. 785)(20.989.983)(M.012)(21.027.$9)
244
244 11139 Acum Amtr . Ca Lease
2447 G-sUS S
244 P SG
244 PTO SO
245
2451
2452 R-c.~-
245245 Tot Acm Prviio fo Amrtaton B18 (402,210,256)(380,624.638)(21,585.618)(38.012)(21,23,630)
245
245
2457
245245 Su of Am bV Fac246S (17.781,84)(17.08,610)(695.23)(-'23)
2461 DG
2462 OGU
246 SE (859.911)(803.273)(56.63)(56,38)
246 SO (255.194.019)(240.50.33)(14.687.68)(14.687,684)
2465 CN (81.571.22)(78,2,372)(3.314.85)(3.314.856)
246 SSGCT (623.69)(58.33)(38.36)38.36 0
2467 SSGCH (19.979)(18.834)(1,145)(1.145)
246 SG (46.159.581)(43.367.878)(2.791.70)(76.372)(2,86.075)
246 Less Ca Leas ...
2470 Tota Pro For Amn by Fac (42.210,256)(38.624.638)(21.585.618)(38.012)(21.623.630)
3
IDHO REVISED PROTOOL Pag3.0TOI
Rev Adim (Tab 3)
TOTAl
3.1 3.2 3.3 3.4 3.5 3.6TemReveueEffec Pri JoltUse Whee Gn Tag
Total Noze No No Chan Ree Re R_
1 Op Reue:2 Ge Buins Revue 16.979.728 (802.827)6.218,962 11.56.593 Inpata4 Spe Sal5 Ot Opra Rev 1.04.70 (5.784)1,146.744 27.153
6 Tot Op Re 18,028,43 (802.827)6.218,962 11,563.59 (5.784)1,146.744 276.153
7
8 Opat Exses:9 Stee Pructio10 Nu Pi11 Hy Pro
12 Ot "-Sup
13 Trasmiio14 D1ti (36.729)(36.72)15 Cu Acti916 Custo Ser & In
17 Sa18 Adtr & Ge
19 Tot O&M Ex (36.72)(36.729)20 De21 Am
22 Taxes Ot Th Inco23 In Tax: Fed 5,782.46 (2.23)2.077.817 3.86.512 10.34 38.139 92265
24 Sla 785741 (38.44)282.341 524.987 1,06 52.06 12.537
25 De In Taxes
26 kwlmt Tax Cr Ad.
27 MI Re & Exnse 758,103
26 Tot Op Exnses:7.289.577 (30.681)2,36.158 4,38,499 (24,978)43,201 104.803
29
30 Op Re For Ret:10.73.85 (49.146)3,58,80 7,175.09 19,13 711.54 171,350
31
32 Ra Ba
33 EI PIIn see
34 PI Hefo Fut Use
35 MIe Deem De
38 EJ PI Ac Ad37 Nu Fuel38 Pr
39 Fue Stok40 Ma & Supp41 Woi Cl42 We Lo
43 Mie Ra Ba
44 Tot EI Pl:
45
46 De:
47 Acm Pr For De
48 Ac Pr For Am
49 Aium De Incom Tax50 lN IT
51 Cuto Ad For Co
52 Custom Ser Deit53 Mice Des (2.68.541)
54
55 Tot De:(2,68,541)
58
57 Tot Ra Ba (2.682.541)
58
59
60 Estima ROE lm 4.342%-0.197%1.~2.842'"0.00'"0.28 0.06%
81
82
63
84 TAX CACULTI:
8568 Op Re 17,307,062 (80827)6.218.96 11.5659 30.96 1.148744 27153
87 Ot Dect
68 Intt (AFUO)
69 In70 Sch "M Ad71 Scle "M De
72 Inc Be Tax 17.307.062 (802.827)8.218.962 11.56.59 30,96 1.146.744 276.153
73
74 Slae Ine Tax 785.741 (3.44)282.341 524.987 1,06 52.062 12.537
7576 Tax In 16.521.322 (768,379)5.938.821 11,03.606 29,559 1,094.681 26.615
77
78 Fed In Tax 5,762.46 (26.23)2.077.817 3.86.512 10,34 38,139 92,265
IDAHO REVISD PRO Pa 3.0.1 Total~Ac (Tab 3)
TOTAL
3.7 3.8 0 0 0.0 0 0
CIaSlor SO~ Em~Al 0 0 0 0 0
1 Op ~ue:2 Ge Bus Re3 Inme
4 Spii Sale5 0I Op Reve (36.424)
6 Tot Op Re (36.424)
7
8 Op Ex:9 Ste Pr10 Nucle Pr11 Hy Pr12 0I Po SU
13 Trasmiio
14 Dilr15 Cuto Ac
16 CUsto 8e .. In
17 Sal18 Adtr .. Ge
19 Tot O& Ex20 De21 Am
22 Tax 0I Th ii
23 ii Tax: Fec (123.94)(25.29)
24 Sta (16,72)(34.418)25 De In Tax26 Intm Tu Cn Ad
27 MI R- .. ex.758.103
26 Tot 0p Ex:(139.21)470.39
29
30 Op Re For Rw (22.60)(470.39)
31
32 Ra. Ba:
33 EI Pl In Ser
34 PI He fo Fut Us35 Mi De De
36 Ef P11l Ac Ac
37 Nu Fuel38 Pr
38 Fue Sto40 .M8" Su41 Wor Cl42 Wea i.
43 Mi Ra a..
44 ToI EI Pl
4S
46 De:
47 Acm Pi ForDe46 Ac Pi For Am
49 Ac De In Tax50 Unam IT
51 Cu Aå For Con52 Cu 8e De53 ~ De (2,82.541)
54
55 Tot De:(2.68.541)
58
57 ToI Ra Ba (2.68.541)
58
5980 Esti RO lm -0.091%-0.121%0.00 0.00%0.00 0.00%0.00
81
82
63
84 TAXCAUlTl
8566 Op ~(36424)(758 103)87 Ot De88 In (AF)
69 InI70 Schii "M Ad71 Sc'M" Deucli
72 Incom il Tax (36,424)(758 103)
7374 Sta Inc Tax (18.72)(3.418)
75
78 Tax ii (351,898)(72,68)
n78 Fec in T_(123.09)(25.29)
Rocky Mountain Power PAGE 3.1
Idaho Genral Rate Case. December 2007
Temperaure Normalization
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Residential 440 1 335.909 10 Situs 335,90
Commercial 442 1 (1,138.736)10 Situs (1.138,736)
Total (802,827)(802.827)3.1.1
Description of Adjustment:
This adjustment normalizes revenues in the test period by comparing actual loads to temperature normalized loads.
Weather noralization reflects weather or temperature patterns which were measurably diferent than noral. as
defined by using 30-year historical studies by the National ocanic & Atmospheric Administration. Only residential and
commercial sales are considered weather sensitive. Industrial sales are more sensitive to speific economic factors.
This revenue adjustment coesponds with temperature adjustments made to system peak. energy loads and net poer
costs.
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Rocky Mountain Power PAGE 3.2
Idaho General Rate Case. December 2007
Revenue Normalization
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Residential 440 1 4,962,075 10 Situs 4,962,075
Commercial 442 1 446,447 10 Situs 446,441
Industrial 442 1 1,38,351 10 Situs 1,38,351
NuWest 442 1 331,830 10 Situs 331,830
Monsanto-Firm 442 1 26,421 10 Situs 26,421
Monsato-Non Fir 442 1 (2,191,355)10 Situs (2,191,355)
Monsanto-Curtiled 442 1 1,254,684 10 Situs 1,254,684
Public Street & Highway 444 1 4,509 10 Situs 4,509
Total 6,218,962 6,218,962 3.1.1
Description of Adjustment:
Included in test per revenues are a number of items that should not be included in regulatory results such as the
SPA creit. Additionally, special contrct revenue needs to be normalized in regulatory results. This adjustmnt
normalizes these revenues to reflec a normal amount of test period revenues for these items.
Rocky Mountain Power PAGE 3.3
Idaho General Rate Case. December 2007
Effective Price Change
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED ~
Adjustment to Revenue:
Residential 440 2 10 Situs
Commercial 442 2 (8,650)10 Situs (8,650)
Industrial 442 2 (166)10 Situs (166)
NuWest 442 2 10 Situs
Monsanto-Firm 442 2 10 Situs
Monsanto-Non Firm 442 2 10 Situs
Monsanto-Curtailed 442 2 10 Situs
Public Street & Highway 44 2 10 Situs
Total Typ 2 Adjustments (8,816)(8,816)3.1.1
Residential 440 3 2,708,570 10 Situs 2,708,570
Commercial 442 3 15,462 10 Situs 15,462
Industrial 442 3 2,182,285 10 Situs 2,182,285
NuWest 442 3 249,078 10 Situs 249,078
Monsanto-Firm 442 3 354,454 10 Situs 354,454
Monsanto-Non Firm 442 3 5,871,606 10 Situs 5,871,606
Monsanto-Curtailed 442 3 10 Situs
Public Street & Highway 44 3 190,954 10 Situs 190,954
Total Type 3 Adjustments 11,572,409 11,572,409 3.1.1
Description of Adjustment:
The tye 2 adjustment adjusts for Schedule 19 biled cheaper revenues. During 2008, 149 customers served on
Schedule 19 were moved to either Schedule 6 or 23 beause the Company's analysis showed their bils would be lower
under the new schedule. In addition, the Company proposes to move an additional 19 customers at the conclusion of
this case. These moves resulted in a small revenue decrease compared to the test year. Schedule 19 is closed to new
service.
The type 3 adjustment reflects the revenue increases as stipulated in Idaho rate case PAC-E-07-o5. An all part
settlement was reached and a stipulation filed with the commission on November 6, 2007. The stipulation was approved
by the Commission on December 28, 2007 with an effective date of January " 2008. Therefore, it is necessary to
annualize the effects of a price chançie into results for the 12 months ended December 2007.
Description of Adjustment:
During 2007 severl entries related to joint use revenues were booked to the incorrect FERC accounts andor locations.
This adjustment corrects the accounting data to reflect proper account assignment and alloction factors.
Rocky Mountain Power Pa 3.4.1
Idaho General Rat Case. Deember 2007
Jont Use Reveue Corrttn
Adjustmen to 207 Jot Use Accti Revenes
AD joint us action reenu we pote to
FERC 456. The revenu should ha ben split betw 456 an 415 base
on wh th c:ding expe _re rerd.
FERC Locon Facr Pe Books CY 207 Corte 2007 Adustmnt Sury of Adustent RelPage
Acount
456 1 SG 95.311 (95,311)Acct Facor Amunt
456 503 UT 319 (319)456 SG (95,311)3.4
456 5404 UT 255 574 319 456 UT 3.4
456 1050 OR 41.007 41.007 456 OR (442,969)3.4
456 10800 OR 141.153 11,259 (129.894)456 WA (96.043)3.4
456 113000 OR 55.741 1.868 (53,873)456 WYP (1.163)3.4
456 122000 OR 298,573 1.255 (297,318)456 CA (4,753)3.4
456 12600 OR 319 319 415 NUTI 64.239 3.4
456 12800 OR 2,951 7.818 4.86 Tot 3.4
456 1290 OR 50 500
456 13200 OR 574 574
456 13300 OR 2.079 2.878 799
456 13400 OR 14.289 4.231 (10.58)
456 13600 OR 1.000 1,00
456 24000 WA 38.052 (36,052)
456 24600 WA 58,991 1,000 (57,991)
456 56300 WYP 1.50 255 (1,245)
456 567300 WYP 1,500 1.50
456 572000 WYP 255 (255)
456 575000 wyp 5.96 5,960
456 576000 wyp 1.163 (1,163)
456 651000 CA 58.373 20,908 (37,465)
456 65500 CA 6,96 27.495 20.532
456 856100 CA 1,573 13.753 12.180
415 10500 NUTIL 1.067 1,067
415 10800 NUTIL 29,803 29.80
415 122 NUTIL 26,216 26,216
415 133000 NUTIL 2,952 2.952
415 13400 NUTIL 7.021 7,021
415 240000 NUTIL 207,358 207.358
415 24600 NUTIL 172,427 172.427
415 57600 NUTIL 1.163 1.163
415 65500 NUTIL 64.435 64.435
415 65100 NUIL 127,797 127,797
784.393 784.393 (0)
Rocky MoutlÏß Po
Idaho General Ratl Case. Dember 2007
Joint Uie Revue Comti
Eac ni an en is poto trsfer jo us res fr an expac to a reue ac. Th re ent sh
ha ci ou on th sa FERC act an lo asth or chare. bu in wa poed at a high leel,
le ofet ai in FERC 416. 59 an 59.
FERC Lo Factor PeBoklCY Cote AdutmentAccount2072007
416 105 NUll (1.067)1,67
416 108 NUll (29.80)29.80
416 1220 NUll (26,216)26,218
416 133 NUTI (2,95)2.952
416 134 NUIl (7,021)7.021
416 240 NUl (207.35)207,35
416 246 NUTI (172.427)172.427
416 5760 NUIl (1.163)1.183
416 65 NUTll (64,435)64,43
416 65100 NUIl (127,797)127.797
59 54 UT (574)574
593 1050 OR (41,007)41.007
593 108 OR (11.259)11.25
593 1130 OR (1.88)1.88
593 122 OR (1,55)1.255
593 126 OR (319)319
59 128 OR (7,818)7,818
59 129 OR (50)50
593 132 OR (574)574
593 133 OR (2.878)2.878
59 134 OR (4.231)4.231
59 136 OR (1.00)1.00
593 246 WA (1.00 1.00
59 58 W'P (255)25
593 56 WY (1.50)1.50
593 515 WY (5.96)5.96
59 85100 CA (20.90)20.90
513 65 CA (27.495)27.49
59 65100 CA (13.753)13.753
598 90 SN 764,39 (764,39)
Pag 3.4.2
Sumry of Adutm Rtf. Pag
Acet Factr Amot
593 UT 574 3.4
59 OR 72,710 3.4
593 WA 1,00 3.4
59 W'P 7.715 3.4
593 CA 62.156 3.4
59 SNP (78,39)3.4
418 NUTIl 64.23 3.4
S 3.4
Rocky Mountain Power PAGE 3.5
Idaho General Rate Case. December 2007
Wheeling Revenue
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenues 456 1 (277,028)SG 6.048%(16,754)3.5.2
Other Electnc Revenues 456 2 294,642 SG 6.048%17,820 3.5.2
Other Electnc Revenues 456 3 17,931,776 SG 6.048%1,084,503 3.5.2
Other Electric Revenues 456 3 928,810 SE 6.586%61,176 3.5.2
18,878,200 1,146,744
Adjustment Detail:
Actual Wheeling Revenues
Total Adjustments
Normalized Wheeling Revenues
56,190,220
18,878,200
75,068,420
3.5.1
3.5.2
3.5.2
Description of Adjustment:
The Company expects to receive additional amounts over 2007 levels regarding the Malin-Indian Springs contract.
Also, there were various transactions regarding wheeling revenues dunng 2007 that the Company does not expect
to occur in the test period. These transactions relate to vanous pnor penod adjustments and contract terminations.
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Rocky Mountain Power PAGE 3.6
Idaho General Rate Case. December 2007
Green Tag Revenue
TOTAL IDAHO
ACCOUNT bJ COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenues 456 1 685,281 SG 6.048%41,445 3.6.1
Other Elec Revenues 456 1 (43,081)CA Situs 3.6.1
Other Eletrc Revenues 456 1 (642,200)OR Situs 3.6.1
41,445
Other Electric Revenues 456 3 3,880,782 SG 6.04%234,707 3.6.1
Oter Electric Revenues 456 3 (42,669)CA Sits 3.6.1
Other Electric Revenues 456 3 (636,055)OR Situs 3.6.1
3,202,058 234,707
Descrition of Adjustment:
A market for gree tags or renewable energy credits is developing where the tag or "green" trits of qualifyng
poer prouction facilities can be detached and sold separately from the power itself. These green tags or credits
may be applied to met renewable portolio standards in various states. Currently, California and Oregon have
renewable portolio standards that limit the Company's abilty to sell green tags. This adjustment reverses actual
sales and allotes the sales for the 12 months ended December 2008 to the remaining jurisdictons.
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Rocky Mountain Power
Idaho General Rate Case December 2007
Green Tag Revenues
Page 3.6.2
Wind Generation. MWH . from GRID
Foote Creek I
Glenrock Wind
Goonoe Wind
High Plains Wind
Leaning Juniper
Seven Mile
Rolling Hills
Mareng
Total Wind Generation. MWH
Total Renewable Energy Credits - MWH
103,423
280,927
307,717
609,287
1,301,355
143,089
157,490
166,068
466,647
1,768,002
70.61%
1,248,380
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936,285
$3.50
$3,276,998 To 3.6.1
$1,64,375
$1,630,623 To 3.6.1
Qualified Facilties & Purchased Power. MWH . from GRID
Rock River i
QF Mountain Wind
Wolverine Creek
Total QF & Purchased Power. MWH
Renewable Energy Credits Allocation
ID/UTIWAIY - SG Factor Allocted Porion
MWH Available for Sale
Percent of Available MWH Sold
Total MWH Sold
Sales Pric pe MWH sold
Total Adjusted Green Tag Revenue
Incremental Change
December 2007 Sales
Incremental Change
Rocky Mountain Power PAGE 3.7
Idaho General Rate Case. December 2007
Clark Storage Revenue
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCTED REF#
Adjustment to Revenue:
Other Electric Revenues 456 1 (6.091.730)SG 6.048%(368,424)3.7.1
Description of Adjustment:
The Clark Storage & Integration Agreement was terminated in December 2007. This adjustment removes the revenue
credit from results of operations.
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Rocky Mountain Power
Idaho General Rate Case - December 2007
S02 Emission Allowances
ACCOUNT ~
Adjustment to Operating Income:Incremental Change 4118 1
Adjustment to Rate Base:
Regulator Deferred Sales 25398
TOTAL
COMPANY
11,510,010
1 (40,728,101)
PAGE
IDAHO
FACTOR FACTOR % ALLOCATED
SE 6.586%758,103
3.8
REF#
3.8.1
SE 6.586%(2,682.541) 3.8.1
Description of Adjustment:
The Environmental Protection Agency has established guidelines that govern the volume of sulfur di-oxide (S02) that can
be emitted from power plants and granted the issuance of S02 emission allowances to cover each ton emitted. Plants
that are not in compliance with EPA guidelines may purchase emission allowances from other companies that have
excess allowances. This adjustment replaces the sales from the historic period and adds back the annual amortization
amount. These sales are amortized over a 15 year period starting in May 2005.
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IDHO REVISD PROTOl Pa 4.0.11~i
o&M Ad (Tab 4)
TOTAL
4.8 4.90 4.9.1 4.9.2 4.9.3 4.9.4 4..5 4.10
Wag & Em Wag & Em Wag & Em Wag & Em Wag & Em Wag & EmBene .e-.Il .Bene . Pro Ben . Pr Ben . Pro MEHC Trait
Re Ex Annun 1 An 2 Ann 3 For 1 Foi2 Fom3 Sav
1 Op Rev:2 Gen Buslne Reen3 In4 Spe Sa5 0I Op Reven 135410
6 Tot Op Reven 135,410
7
8 Op Exes:9 Ste Pi 21.68 n.975
10 Nu Pi11 Hy Pi 3,149 10,57
12 0I "- Sup 1.46 6,60 4,91 21.063 (21.673)
13 Tl'sl 3.5 12.06 (11.041)14 Di 20481 199 68.15 671 (2018)
15 Cus_ Ac 8,416 28.317 (778)
16 C_ se & In 1.50 5,05
17 Sa1. Adlre & Ge--(2ln)16.40 55196 3$,.9
19 Toui O&M Expe (26.1n)26.30 30,3 26.523 88.514 102.04 89,242 291.43
20 De21 Am22 Tax.. Ot Th In23 Inme T_: Fed 5398 (8.789)(10.132)(8.86)(29.573)(34.09)(2.817)(91.77
24 St 7.33 (1.194)(1.377 (1.204)(4.019)(4.63)(4.05)(13.)
25 De In T_
26 in..tm Tax Cr Ad.
27 MI Rev & Expee
28 ToI Opal Ex:35.150 16.323 18.817 16.457 54.92 63.315 55.374 184.5
29
30 Op Re I'OF Rei 100.26 (16.323)(1..8m (16.45)(54.92)(63315)(55374)(184.55)
31
32 Rae Bas: 33 El PlIn Se34 Pl He fo I' Us35 Mi De De
3G El Pl Ac Ad
37 Nu Fue38~
39 Fue Sl40 M. & Sup41 Woi Cap42 WUlri Loa43 MI Ra Ba
44 T ~i El PI
45
46 De:47 Acc Pr FoDepr
48 Ac Pr For Am
49 Ac De in Tax
50 Un lTC51 eu_AdFoCo52 C_ se De53 MI De
54
55 Tot De:
56
57 ToI Ra Bas
58
5860 EsUm RO Im 0.04%-o.l..-O.OO -07%-002..-0.02"-O.02 -0073
61
62
63
64 TAX CALCULTI:
6566 Opra R_161.58 (26.31 (3.32 (26.5)(88,14)(102.04)(89242)(2.43)
67 Ot De
66 Inl (AFUD)
69 Int70 SC'M" Ad71 SC'M" De
n In Be Tax 161.58 (26.30)(30.32)(26.523)(88514)(102.04)(89.242)(297.43)
73
74 St In Tax 7.33 (1.194)(1.377 (1.2)(4.019)(4.63)(4.0)(13.50)
75
76 Taxab In 154.246 (25.112)(28.949)(25.319)(84,495)(97.407)(85.191)(263.93)
7778 Fed in Tax 53986 (8.78)(10.132)(8.86)(29573)(34.09)(2.817)(99.377
IDHO REVse PRTOOL Pa 4. Tol
O& Adtm (Tab 4)
TOTAL
4.11 4.12 4.13 4.14 4.15 4.18 4.17 4.18
A&GCostInAftMgFeComCo DSM Am Me 8I
Gen O&(MEHC)Pota Expe in Ex oe (ME)Remal Sut
1 Op Reven:2 G.- Busins Rev31n~4 Sp Sa5 Ot Op Reven
6 Tot Opti Reen
7
8 Op Ex:9 Ste Pn10 Nuc Pr11 Hy Pn
12 Ot i- Su 1.167.93
13 Tr_mi 156,285
14 Oiti 44.7315 e- Ac 12,421
16 Custa Se & In (2.048,20)
17 Sa18 Ad & Ge (97.48n (147.112)20.83 (225,62)1..075
19 Tot O&M Expe 1.187.93 (97.487)12.421 (147.112)221.83 (2262)(2,04.020)1e.75
20 De21 Am22 Tax.. Ot Th In23 in Taxes: Fed (39,219)32.58 (4.150)49.152 (74.117)7538 68,26 (8.03)
24 $_(53.02)4,425 (56)6.79 (10,071)10.243 92,9 (821)
25 De In T_
26 in Tax Cre Ad.27 MI Rev & Exe
26 TolOpat Ex:724,892 (80,m 7.707 (91,282)137,64 (139.997)(1,270,778)11,215
29
30 Op Rev Far RMw (724.69)60,477 (7.70n 91,2 (137,64)139.997 1,270.77 (11,215)
31
32 Ra Base: 33 I!lec Pl In Se
34 Plan He fa Fui Us35 MI De De
36 EI Pl Ac Ad37 Nu Fue38 Pr
39 Fue St40 Me & Sup41 Woi Cap42 We8l i.
43 Mie Ra Ba
44 Totl! Pl
45
48 De:47 Ac Pr For De48 Ac Pr For Ai
49 Ac De In Tax50 Un IT51 c.Mv Fare-52 c. Se Deit53 Mi De
54
55 To\l De:
56
57 Tot Rat Ba
58
5960 Es RO im .(1.87%0.024%~.00%0.03%~Jl%0.05 0.50 ~.00%
81
62
&3
64 TAXCACULTl
8566 Op Re (1.187.93)97.487 (12.421)147,112 (21.83)2262 2.04.0 (18.075)
87 Ot De
66 im (AFUO)89~70 SC'M" Add71 Sc "M De
72 In Be Tax (1.167.93)97.467 (12.421)147.112 (221,8)225,623 2.04.02 (1s.75)
73
74 Sl In Tax.(53,024)4,425 (56)8.67 (10.071)1(143 92.98 (821)
75
76 Tax In (1,114.911)93 (11,857)140.43 (211,762)215,38 1,955.04 (17,254)
7778 Fedal In Tax (39,219)32.565 (4.150)49.152 (74,l1n 7538 68,2 (8.03)
IDAHO REVISOPROroOL Pag 4.0.3 Tot
O&M Adjtm (Tab 4)
TOTAl
4.19 4.20
Idaho Pe
Id Inten Ex CashFunBasis
1 Opeat Rev_:2 Geal Buins Rev3 Inte4 Spe Sal5 OI Op Revue
6 Tot Op Revs
7
8 Opra Ex:9 Sleam Ptn10 Nu Ptuc11 Hy Ptuc12 OI Pow Sup13 Trass14 D1tr15 Cus_Accnl
16 Custo Seilc & In17 Sa
18 Adaie & Gene 28.86 1,031,93
19 Tot O&M Expees 28.86 1.031.36
20 Deat21 A.
22 Taxes O1r Th In23 In Taxes: Fed (9.64)(34.78)
24 Stale (1.310)(46.850)25 De In Tax
26 inestm Tax Cre Adl
27 MI Revenue & Expee
28 Tot Opat Expees:17,910 64.30
29
30 Op Rev For R_(17.910)(64.3)
31
32 Ra Bas: 33 EI PI In Se
34 PI He fo Fut Use
35 Mise Deir Debi (28.86)
36 EI PI Ac Ad37 Nu Fue38 Pr
39 Fue Sto40 Ma1 & Sup41 WOI Cap42 WealhLo
43 Mi Rat Bae
44 Tot El Plnt (28.865)
45
46 De:47 Ac Pr For De
4B Acc Pro For Am
49 Ac De In Tax
50 Una ITC
51 Cus_ Ad For Cot
52 Custo Seilc Depo53 Mice De
54
55 Tot De:
56
57 Tot Rate Bae:(28.86)
56
5960 Esti ROE Im .0.06"-0.25'"
61
62
63
64 TAX CACULTI
65
66 Op Revenu (28.85)(1.031,93)67 Ot De
68 Intt (AFUDC)
69 Intt70 Sched "M Adc71 Sc'M' De
72 In Be Tax (28.865)(1.031.936)
73
74 S_in Taxes (1.310)(46850)
75
76 Taxab In (27,55)(985.087)
77
78 Fed Inc Taxes (9.64)(34.78)
Rock Mountain Power PAGE 4.1
Idao General Rate Case. Decmber 2007
Miscaneous General Expense
TOTAL IDAHO
ACCOUNT Im COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Misc. Steam Expense 50 (500,000)SG 6.048%(30,240)4.1.1
Opration Supr & Engineering 54 (3,975)SG 6.048%(240)4.1.1
Other Exses 557 (96,718)SG 6.048%(5,849)4.1.1
Trans. Opetin Survisn & Enginring 580 (7,119)SNPD 4.682%(33)4.1.1
Maint of Mis. Distrbut Plant 598 (1,100)SNPD 4.682%(52)4.1.1
Distbutio Supervsin Exnse 901 (2,658)CN 4.064%(108)4.1.1
lnfonational & Instriol Advertsing 909 (79,139)CN 4.064%(3,216)4.1.1
Ofce Supplies & expenses 921 (89,804)SO 5.755%(5,169)4.1.1
Ofce Supples & expenes 921 (202)WY-ALL Situs 4.1.1
Outide Se 923 (199.624)SO 5.755%(11,489)4.1.1
Miscaneous Geeral Exense 930 (1,210)UT Situs 4.1.1
Misclaneous Genera Expense 930 218,913 SO 5.755%12,600 4.1.1
Total Miscaneus Gel Expese Removal (762,637)(44,097)
Description of Adjustment:
This adjustment remves from results of operations certin miscellaneous expenses that should have been charged to non-regulated
accunts.
,
Rocky Mountain Power Page 4.1.1
Idaho General Rate Case December 2007
Miscellaneous General Expense
Description FERC Factor Amt to Exclude
FERC 506 . Misc. Steam Expense
Sierra Club Settlement Fees 506 SG 500,000
FERC 546 . Operation Super & Engineering
Scottish Power International Assignee Tax Fees 546 SG 3,975
FERC 557 . Other Expenses
Chantable Donations & Sponsorships 557 SG 15,600
Company Plane 557 SG 79,824
Scottish Power International Assignee Tax Fees 557 SG 1,294
96,718
FERC 580 . Trans. Operation Supervision & Eng.
Scottsh Power International Assignee Tax Fees 580 SNPD 7,119
FERC 598 . Maint of Misc. Distribution Plant
Scottish Power International Assignee Tax Fees 598 SNPD 1,100
FERC 901 . Distribution Supervision Expense
Company Plane 901 CN 2,658
FERC 909 . Informational & Instructional Adv
Chantable Donations & Sponsorships 909 CN 25,702
Misc Advertising Expense 909 CN 53,437
79,139
FERC 921 . Ofce Supplies & Expenses
Chantble Donations and Sponsorships 921 SO 1,423
Company Plane 921 SO 47,152
Economic Development Corp of Utah 921 SO 5,788
Employee Gifts, Flower, Parties, Cake 921 SO 4,722
Employee Gifts, Flowers, Partes, Cake 921 wyp 12
Legislative & Lobbyist 921 SO 14,739
Legislative & Lobbyist 921 WYP 176
Misc Offce Supplies Expense 921 SO 7,085
Ranch & Cabin 921 SO 2,456
Retirement Parties 921 SO 6,439
Retirement Parties 921 WYP 15
90,006
FERC 923 . Outside Services
Legislative/Lobby 923 SO 5,630
Misc Outside Services Expense 923 SO 73,222
Ranch Expenses 923 SO 21,822
Rebranding Expense 923 SO 18,636
Retiree Ambassador Expense 923 SO 3,384
Scottish Power International Assignee Tax Fees 923 SO 76,930
199,624
FERC 930 . Mise General Expense
Advertsing/Sponsorships 930 SO 912
Advertising/Sponsorships 930 UT 1,210
Civic Activities 930 SO 175
Utah Economic Development Corpration of Utah 930 SO 20,000
Edison Electnc Institute Membership Dues 930 SO (240,000)
(217,703)
Rocky Mountain Power PAGE 4.2
Idaho Generl Rate Case. December 2007
Remove Non-Recurrng Entries
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED ~
Adjustment to Expense:
1) KATZ Patent Reserv 903 (576,800)CN 4.06%(23,440)4.2.1
2) Capital Surcarg Clearing 922 1 199,282 SO 5.755%11,470 4.2.1
3) FERC Continnt Fees 928 (2,353.550)SG 6.048%(142,341)4.2.1
4) Excise Tax Refund 921 1 179,692 SO 5.755%10,342 4.2.1
5) Clear FY06 Innt to Sucharg 922 652,96 SO 5.755%37,581 4.2.1
6) MCBIT Refund 903 1 (723,360)OR Situ 4.2.1
909 1 (80,530)OR Situs 4.2.1
7) Uabilty Wrie Of 908 100,233 UT Situs 4.2.1
8) Ref Transmission Revenue 566 1 (100,000)SG 6.048%(6,048)4.2.1
90 1 800,000 CN 4.06%32,510 4.2.1
9) Geary Dike Reserve 539 1 1,00.00 SG-6.048%60,479 4.2.1
10) Softre Wrie Of 421 1 (455,40)SO 5.755%(26,211)4.2.1
11) sand Traning Cener Wrie Of 421 1 (1,056,38)SO 5.755%(60,800)4.2.1
931 1 (50,000)SO 5.755%(2,878)4.2.1
TOTAL Norr Adjutments (2,463,863)(109,335)
Descriptin of Adjustment:
A variety of acnting entries were made to expense accunts during 2007 that are either non-recurring in nature or relate to a prir
perid. These trnsactions are removed from results of operations to normalize the test period results. A descption of each item
included above is prvided on Pages 4.2.1 and 4.2.2.
Rocky Mountain Power Page 4.2.1
Idaho General Rate Case December 2007
Remove Non-Recurring Expense
INo. lpostg Date I Text I FERC Acl Amount as Booked I Reference I
1 06/2712007 KATZ Reserve 9031000 2,150,000 4.2.2
081812007 Settlement Payment 9031000 (1,573,200)4.2.2
2 05/3112007 Cap Surcharge Clearng 922~~(199,282)4.2.2
3 0430/2007 FERC Contingent Fees 9283000 (130.272)4.2.2
3 03131/2007 Contingent Fees - Mar 2007 9283000 1,317,268 4.2.2
3 0313112007 Contngent Fees - Mar 2007 928300 1,166,553 4.2.2
4 021281007 Excise Tax Refund 921000 (179,692)4.2.2
5 01/23127 Clr FY06 Incent to Surchr 9220000 (652,960)4.2.2
6 093012007 MCBIT Refund 9032000 666,746 4.2.2
6 various MCBIT Interest and Other Costs 9032000 56,614 4.2.2
6 various MCBIT Settlement Informational Ads 9090000 80,530 4.2.2
7 0912712007 Uability Write Off 90000 (100,233)4.2.2
8 0912712007 Refund Transmission Revenue 5660000 100,00 4.2.2
8 091301007 Refund Transmission Revenue 900000 (800,000)4.2.2
9 121112007 Geary Dike Reserve 539~~(1.00,000)4.2.2
10 081112007 Retire MACE Softare 421200 455,404 4.2.2
11 1012312007 Wnte Off Sanel Training Center Prepaid Lease 4212000 946,218 4.2.2
11 10/2312007 Retire Sandy Training Center Leasehold Improvements 4212000 110.169 4.2.2
11 Discontinued Sandy Training Center O&M 9310000 50,000 4.2.2
2,463.863
Ref#4.2
Rocky Mountain Power
Idaho General Rate Case December 2007
Remove Non-Recurring Expense
Page 4.2.2
Certin accounting entries were made to expense accunts that are eiher on-tie and non-recurrng in natue or relate to a
prr peod. These trsactons are removed frm results of opetins to normliz th test pe results.
1) Ka Patent Reserv: An entr was made in Jun 2007 to reco th contingent libil assoted wi a pending lawsui for
a patent infrngement related to automated telephony (a patent owned by Katz.) The number is base on th telephony usage
over the past six years. In August 2007. the dispute was setted and th resultng paymnt was muc lower than had been
reservd and a corresponding entry was made (the Company reserved $2.1 millon and sett for $576.800). These are
related to a prior peri and shuld be removed.
2) Cap Surcarg Cleari: Capita surcharg clri entr fo th Cote busness unit. The amount previusly
capitalized was written off to FERC accunt 922. This adjustment removes th credit frm 2007 results.
3) FERC Contigent Fees: Estimate for th contngnc changed frm prr mont. as chngs we ided in meawatts
for repo purpses. Th Company under-repoed megawatts over th last 3 yers and estimates tht FERC might require
soe paymnt to cover.
4) Excise Tax Refund: The Company reived a $204 excise tax refu fr the IRS reted to a previos year. Of the total.
$179.692 was crdited to expnse in February 2007. This adjustment removes th crit.
5) Clear FY06 Incetie to Surcharg: Capitl porton of incentie accal orinally boed to 148002 in a pri period. It
shoul have be reversed during the year and boked to th capital surcharge accunt and wasn't. This entry reclasses it out
of 14802 and into th capil surcharg accunt to be alloted to capil project.
6) MCBIT Refund: In September 2007 th Company reached agreement on a fial refu amout fo Muomah County
Business Income Tax conected from customers since 1993. As a result of th settement. the Company set aside $2.2 milion to
cover th customr refund. atteys fees. and oth costs of the settement. The Company mae an entry to incease a
previosly acced reserve. This adjustmnt revees the impac of tht entr on regulted results and removes any other
settement exnses booked in 2007.
7) liabilty Wri Off A libility on th books since 1995 was wrien off becase it had exceed th statue of limitations. A
cotractor ha done so DSM work for th Company in the 90s. We had paid the cotrctor. but there was a small balance in
th liailty that kept accng interest. The contror never bill and we wrote off th balanc after ten years.
8) Refund Transission Revenue: The Company had a dispute wih a trsmissio customer rerding unreserd use
chs over a peri of several years. In 2006 the Company offere to refund $80.000 and established a reserve for that
amount. The isue subsequentl went to FERC which ruled th Company only needd to refund $100.000. at which time the
company reversed th old resere and establishe a payable for $100,00. This adjustmnt reverses the impact of these
entes in reulted results.
9) Geary Dike Reserv: The Geary Dike faile and fl a go course, farmlan. an state hiay on Ju 7, 200. The
Company inilly reserved $1 millin in June 200, and in November 2007 an aditional $1 mill was reseed for addital
liabilit facing the Company. The Company subsequently determine th event met th crera for an injuries and damages
insurnc clim. In December 207. the $2 milion reserv was revered and approprite entrs were mad corespoding to
the insurance clim. This adjustment remves the net impact of reversng the resere in 2007.
10) Micellanes Wrie Offs: In Augt 2007 the copany determined th Mapping and Conecvi Enabler (MACE)
softre package was no longer used and was written off. The loss on dipositin was rerded to FERC accnt 421 and this
adustment removes it from results.
11) In October 207 th coany reliquishe twthirds of it lease fo the Sandy Traini Cener facilitis. A poon of th
prepaid lease and varius leaseho imprvements at the ceter were wren off to FERC Acct 421. This adjustment
remves the wr off frm results and redces O&M expens to reflct the new leas agreement.
Rocky Mountain Power PAGE 4.3
Idaho General Rate Case. Deember 2007
Irrgation Load Control Program
TOTAL IDAHO
ACCOUNT Tvoe COMPANY FACTOR FACTOR % ALLOCAWD Bæ
Adjustment to Expense:
Othr Purchased Power 557 1 (1,191.104)SG 6.048%(72,037)4.3.1
Oter Purchased Power 557 1 1,191.104 10 Situs 1,191.104 4.3.1
1.119.066
Oter Purchas Power 557 3 5.378.896 10 Situs 5.378.896 Below
T otallncentive Creit 6,570.000 6.570.000
Adjustment Detail:
2008 Prm Particpation (MW)
$lW Incentis
Total Incntive Credit
219
$ 30.00
$ 6.570,000
Description of Adjustment:
Payments made to Idaho irrgators as part of the Idaho Irrgation Load Control Proram are system allocated in th unadjusted data.
This adjustment situs assigns the payments to Idaho. The reallocation is required as DSM costs are situs assigned to th states in
which the costs are incurred to match the benefit of reduce load reflected in allotion factors. Incentive payments wil incease in
2008 due to a signifcant rise in participation. This adjustment incrases incntive payments. and additional curtilment is reflected
in Idaho load used to calculate jurisdictonal allocation factors in this case.
Pag 4.3.1
Roc Moin _Id Ge Ra C_ . De 2001in Lod Con Pr
Ca Yea Caleda Moth20 Gran Tot
FEAr Acc Acc Loc Allti Cod 1 2 3 6 7 8 9 10 11
557~~514511 70 SG 687 738 10862 179156 64959 490377 /4443 9146 119048653SG30530553SG27527554SG3939
57200 SG /31 /3
Gra Tot 38 961 738 10862 119461 649596 490377 (448433 9746 1191104
ReU4.3
ll~lø¡rHi~lΡl~.;~::" ....; ".':;';1.:;.~:;.: '..,'.. '.. (iøf~ ¡ ;.~...~';..... ¡l)....U~-.-: ig"-.liJ~~tri;"t. ~9;'~"'.,liI-ir' ,f"it-
Pag 4.3.2
Rocky Mountain Power
Idaho General Rate Case - December 2007
Irrigation Load Control Program
Incremental Load Adjustment
Schedule 10 June July Aug Sept
At Sales Level
Coincident Peak (CP)264,769 302,879 196,237 179,762
Idaho Scheduled Program 2007 18,957 25,064 24,187 20,323
Gross CP Before Curtailment 283,726 327,943 220,424 200,085
Non-Coincident Peak (NCP)430,113 414,136 385,328 .333,493
CP/NCP Percent 66.0%79.2%57.2%60.0%
Estimated Irrigation Load Control . (194,000)(219,000)(210,000)(191,000)
CP/NCP Percent 66.0%79.2%57.2%60.0%
Curtilment Level ~ Sales (127,973)(173,420)(120,129)(114,594)
Less: Idaho Scheduled Program 2007 18,957 25,064 24,187 20,323
Adjustment for COS (KW At Sales)(109,016)(148,356)(95,942)(94,271)
At Input Level
Line Losses 105.697%105.697%105.697%105.697%
Curtailment Level ~ Input (Rev Req)(135,263)(183,300)(126,973)(121,122)
Idaho Scheduled Program 2007 ~ Input 20,037 26,492 25,565 21,481
Adjustment for JAM (KW At Input)(115,227)(156,808)(101,408)(99,641) Page 10.14
Rocky Mountain Powr PAGE 4.4
Idaho General Rate Case. Deçember 2007
Blue Sky
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED Em
Adjustment to Expense:
Customer Serice 909 1 (4,512)CN 4.064%(183)4.4.1
Customer service 909 1 (5,617)CA Situs 4.4.1
Customer servce 909 1 (8,280)10 Situs (8.280)4.4.1
Customer Servic 909 1 (54.682)OR Situs 4.4.1
Customer servce 909 1 (189.264)UT Situs 4.4.1
Customer Servce 909 1 (16.968)WA Situs 4.4.1
Customer Serv 909 1 (13.604)WY-ALL Situ 4.4.1
Administrtive & General 921 1 (7)SO 5.755%(0)4.4.1
Administrtive & Genel 921 1 (610)CA Situs 4.4.1
Adinistrative & General 921 1 (1.264)10 Situs (1,264)4.4.1
Administrtive & General 921 1 5.130 OR Situs 4.4.1
Administrtive & General 921 1 (16.813)UT Situs 4.4.1
Administrtive & General 921 1 (1.555)WA Situs 4.4.1
Administratie & Genel 921 1 (1.862)WY-AL Situs 4.4.1
Administrtive & General 922 1 (154.422)SO 5.755%(8.888)4.4.1
Administrative & Generl 923 1 (20.976)SO 5.755%(1.207)4.4.1
Administrative & Genral 923 1 (40.133)UT Situs -4.4.1
(525.441)(19,823)
Description of Adjustment:
This adjustment removes from results above the line expenses associated with the Blue Sky program.
Rocky Mountain Power
Idaho General Rate Case. December 2007
Blue Sky Adjustment
To insure non-participants do't subsidize the Blue Sky Progrm, all revenues and expenses charged
above the line are removed from results.
These charges were all made to the Blue Sky cost center, 12348, or individual orders. They are summaried
below.
Amount
Cost Center
12348
Açcunt Factor Blue Sky Qn Total
909 CN 4,512 4,512
909 CA 5,617 5,617
90910 7,587 694 8,280
909 OR 45,818 8,86 54,682
909 UT 172,910 16,354 189,264
909WA 16,968 16,968
909 WYP 13,604 13,604
921 SO 7 7
921 CA 610 610
921 10 1,264 1,264
921 OR (5,130)(5,130)
921 UT 16,813 16,813
921 WA 1,555 1,555
921 WYP 1,862 1,862
922 SO 154,422 154,422
923 SO 20,976 20,976
923 UT 40,133 40,133
495,017 30,423 525,441
Page 4.4.1
Roc Mountain Power
Idaho General Rate Case. December 2007
K2 Risk Mgmt System
PAGE 4.5
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED B£
Adjustment to Expense:
Amortization Expnse 4041P 1 (131,919)SO 5.755%(7,593)4.5.2
Ga I Loss on Sales 421 1 (2,453,790)SO 5.755%(141,228)4.5.1
Ofce Supplies 921 1 (774,818)SO 5.755%(44,595)4.5.1
Administrative Expense 922 1 (42,892)SO 5.755%(2,469l 4.5.1
(3,403,419)(195,884
Descrition of Adjustment:
Th adjustment removes the effect of th K2 Risk Management System frm reults of opetins. This project was capitalized
during calendar year 2006. However, the projec was wrien-ff in Marc 2007 beuse the proje was deemed not used and usefuL.
This asset is not included in the beginning rate base balance for this case.
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Rocky Mountain Power
Idaho General Rate Case. December 2007
Generation Overhaul Expense
PAGE 4.6
Adjustment to Expense:
Generation Overhaul Expense - Steam
Generatin Overhaul Expense - Oter
TOTAL
ACCOUNT .!COMPANY FACTOR
510 1 (123,863)SG
553 1 2.401,565 SG
2,277,702
IDAHO
FACTOR % ALLOCATED B;
6.048%
6.048%
(7,491) 4.6.1145,245 4.6.1
137,754
Description of Adjustmnt:
This adjustment normalizes generation overhaul expnses using a four year average methoology. Overhaul expenses from 2004 -
2007 are escalated to a 2007 level using Global Insight indices and then those esclated expenses are averaged. For new generating
units, which include Currnt Crek and Lake Side, the four year average is compnsed of the overhaul expense planned for the first four
years these plants are operational. The actual calendar year 2007 overhaul costs are subtracted from th four year average which result
in this adjustment.
Rocky Mountain Power
Idaho General Rate Case December 2007
Generation Overhaul Expense
FUNCTION: OTHER
Period
Calendar Year 2004
Calendar Year 2005
Calendar Year 2006
Calendar Year 2007
4 Year Average
Overhaul Expense
2,264,000
545,000
2,940,000
2,860,000
2,152,250
New Plant Overhaul Expense
Lake Side Plant - 4 Year Average
Currant Creek Plant - 4 Year Average
Total New Plant Overhaul Expense
Total 4 Year Average - Other
Base Year December 2007 Overhaul Expense - Other
Total 4 Year Average - Other
Adjustment
· Escalation Rates: Ref 4.6.3
FUNCTION: STEAM
Period
Calendar Year 2004
Calendar Year 2005
Calendar Year 2006
Calendar Year 2007
4 Year Average
Overhaul Expense
23,193,000
25,845,753
29,613,264
28,560,541
26,803,140
Total 4 Year Average - Steam
Escalation Rates
to 2007 · Escalated Expense13.27% 2,564,4018.53% 591,4733.55% 3,04,379
2,860,000
2,265,063
1,479,500
3,040,000
4,519,500 Ref 4.6.2
6,784,563
4,382,998 Ref 4.6.2
6,784,563
2,401,565 Ref 4.6
Escalation Rates
to 2007 · Escalated Expense14.08% 26,457,8618.49% 28,038,9553.63% 30,689,358
28,560,541
28,436,679
28,436,679
Base Year December 2007 Overhaul Expense - Steam
Total 4 Year Average - Steam
Adjustment
28,560,541 Ref 4.6.2
28,436,679
(123,863) Ref 4.6
· Escalation Rates: Ref 4.6.3
Page 4.6.1
Rocky Mountain Power
Idaho General Rate Case December 2007
Generation Overhaul Expense
Existing Units
Calendar Calendar Calendr Calendar
Yr2004 Yr2oo5 Yr2006 Yr2007
By Plant
Bluell 73.934 2,677913
Carbon 4,472.000 (113.331 )723.024 24,146
DaveJohnston 959.000 5,255,000 30.90 3,279,981
Gadsby 1,293,00
Hunter 117,000 6,916,750 3,910,432 8.171,859
Huntington 1,511.000 6,533.000 7.575.000 (39.00)
JimBriger 5,020.00 5.846.000 5.904.000 6,815,000
UttleMt 139.00
Naughton 579,00 1,348,334 3,648.974 4,86.643
WVailey 40,000
Wyoak 678.000 5.629.00
Camas 418.00
Cholla 5.771,000
Colstrp 1,014,000 925,00 1.300.000
Craig 1,536.000 60,000 44.000 1,376,000
Hayden 243,000 745.00 90,000
Henniston 2.224,000 545,00 2,383,000 2.860.000
Total 25,457,000 26,390,753 32.553.264 31,420,541
By Function Ref. 4.6.1
Steam 23.193.000 25,84,753 29,613,264 28,560.541
Otr 2,264,000 545,00 2,940.000 2,860,000
Total $25,57.000 $26,390.753 $32.553.264 $31,420.541
New Generating Units.
Acual Budgt
Calendar Calear Calendar Caledar
Yr2oo7 Yr2008 Yr2oo9 Yr2010
Currnt Crek 1.522.998 1,725.00 7,079,000 1,833,000
Lake Si 650,000 1.818,000 612.00
1,522,998 2,375.00 8.897.000 2,445.000
.Curnt Cr & LakeSi are both Fun . Ot
Base Year December 2007 Overhaul Expense. Other
2007 Existing Plant: 2.860.000
2007 Currnt Crk : 1.522,998
4.382.998 Ref. 4.6.1
Caar 4 Year
Yr 2011 Average
. 3,040,000
2.838,000 1,479,500
2,83,000 4,519.500 Ref. 4.6.1
Pag 4.6.2
Rocky Mountain Power
Idaho General Rate Case December 2007
Generation Overhaul Expense
Global Insight Escalation Rates: OTHER
Other Maintenance indices (JEOMMS)
Escalation Rate to 2007
Global Insight Escalation Rates: STEAM
Steam Maintenance indices (JEFMMS)
Escalation Rate to 2007
~~~~
1.236 1.290 1.352 1.400
13.27%8.53%3.55%~~~~
1.300 1.367 1.431 1.483
14.08%8.49%3.63%
Pag 4.6.3
Rocky Mountain Power
Idaho General Rate Case. December 2007
Preliminary Coal Plant Exp
PAGE 4.7
TOTAL IDAHO
ACCOUNT Ig COMPANY FACTOR FAÇTOR%ALLOCATED ~
Adjustment to Expense:
IPPU3 Development Cost Write-Of 557 (2.969,240)SG 6.048%(179.578)4.7.1
Brier U5 IGCC Deferrl Write-557 (424,092)SG 6.048%(25.649)4.7.1
Hunter 4 Wrie-557 (102.96)SG 6.048%(6,227l 4.7.1
(3,496.295)(211.454
Descñption of Adjustment:
The Company was planning to build 3 coal units: IPP unit 3, Bridger unit 5, and Hunter unit 4. The expenses the Company incrred
for these abandoned projects were wrtten off to FERC account 557. This adjustment removes these expenses from results.
Rocky Mountain Power
Idaho General Rate Case December 2007
Preliminary Coal Plant Exp
Page 4.7.1
IPPU3 Development Cost Wrie-Off
Impairment Loss
Impairment Loss
Impairment Loss
13,888
13,888
2,941,463
2,969,240
Bridger IGCC US Deferral Write-Off
Mise Projec Expense Write-ff
Mise Project Expense Wrie-off
Mise Project Expense Write-ff
Mise Projec Expense Write-off
184,314
175,244
102,938
(38,404)
424,092
Hunter 4 Write-Off
Permitting Expense Write-Off 102,964
Rocky Mountain Power PAGE 4.8
Idaho General Rate Case. December 2007
Rent Expense
TOTAL IDAHO
ACCOUNT I:COMPANY FACTOR FACTOR % ALLQCATED ~
Adjustment to Expense:
Rents 931 1 (454,726)SO 5.755%(26,1n)4.8.1
Adjustment to Income:
Rent of Electric Propert 45 1 (1,872,794)UT Situs 4.8.1
Rent of Electc Propert 454 1 1,872,794 SO 5.755%107,789 4.8.1
Rent of Elecric Propert 454 2 479,916 SO 5.755%27,622 4.8.1
479,916 135,410
Description of Adjustment:
This adjustment removes from results of operations rent expense of unoccupied offce space. It also corrects the allocation for sub-lease
incme in the unadjusted results and annualizes the sub-lease rental income of agreements entered into during 2007.
Rocky Mountain Power
Idaho General Rate Case - December 2007
Rent Expense
Page 4.8.1
Rent Expense:
Unused.~Description Square Footage Leased For Amount ~
1 One Utah Center Sub-lease #5 3,261 $16.83/sf 54,883 SO
2 One Utah Center Sub-lease #6 4,428 $16.831sf 74,523 SO
3 Lloyd Center Mall - Suite 300 $4,425/mo.4,425 SO
4 Lloyd Center Mall - Suite 304 $2,567/mo.30,804 SO
5 Lloyd 700 Building - Suites 500 & 519 13,210 $21.96/sf 290,092 SO
Total Adjustment to Expense 454,726
Rent Income:
Reverse situs assigned OUC sub-
6 leases (1,872,794)UT
Re-allote sub-leases on system
7 factor 1,872,794 SO
8 OUC 22nd Floor - 12 Months $39,993/mo.479,916 SO
Total Adjustment to Income 479,916
Notes:
Lines 1-2: The sublease terms are $1/mo plus operating expenses. Adjustment removes 12 months rent expense
from the base period.
line 3: This lease expired on January 31, 2007. Adjustment removes 1 month rent
expense from the base period.
Line 4: Vacant since January 2007. Adjustment removes 12 months rent expense from
the base period.
Line 5: Vacant for all of 2007. Adjustment removes 12 months rent expense from
the base period.
Lines 6-7: Sub-lease income from tenants occupying six floors of the One Utah Center
was being directly assigned to Utah. This adjustment reverses the situs-assigned
revenue and allocates it on the System Overhead (SO) factor.
line 8: 15,731 sq. ft. of offce space was unocupied until December 1, 2007, at which time it
was subleased for $39,993/month ($25,563 for space at $19.50/sf and $14,430 for contribution
to common area maintenance). The adjustment annualizes the rental income on
this offce space.
Rocky Mountain Power PAGE 4.9
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Annualization 1
TOTAL IDAHO
ACCOUNT Im COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Steam Generation 500 2 46,608 SG 6.048%2,819
Steam Generation 501 2 2,122 SE 6.586%140
Steam Generation 502 2 52,687 SG 6.048%3,186
Steam Generation 505 2 4,779 SG 6.048%289
Steam Generation 506 2 104,790 SG 6.048%6,338
Steam Generation 506 2 (58)SSGCH 5.731%(3)
Steam Generation 510 2 8,207 SG 6.048%496
Steam Generation 511 2 20,508 SG 6.048%1,240
Steam Generatin 511 2 (23)SSGCH 5.731%(1 )
Steam Generation 512 2 81,351 SG 6.048%4,920
Steam Generation 512 2 (700)SSGCH 5.731%(40)
Steam Generation 513 2 30,976 SG 6.048%1,873
Stea Generation 513 2 2 SSGCH 5.731%0
Steam Generation 514 2 7,186 SG 6.048%43
Steam Generation 514 2 (62)SSGCH 5.731%(4)
Hydro Geration 535 2 11,585 SG-6.048%701
Hydro Generation 535 2 10,914 So-U 6.048%660
Hydro Generation 536 2 120 So-P 6.04%7
Hydro Generation 537 2 1,507 SG-P 6.04%91
Hyro Generation 537 2 273 So-U 6.048%16
Hy Geration 539 2 10,059 SG-P 6.04%608
Hyd Generation 539 2 10,342 SG-U 6.048%625
Hyro Generation 542 2 794 SG-P 6.048%48
Hydro Generation 542 2 210 SG-U 6.04%13
Hyro Generation 54 2 1,016 SG-P 6.04%61
Hydro Generation 54 2 561 So-U 6.04%34
Hydro Generation 544 2 2,324 SG-6.04%141
Hydro Genration 54 2 798 So-U 6.04%48
Hydro Geration 545 2 1,094 So-P 6.048%66
Hydro Genetion 545 2 479 So-U 6.04%29
Other Power Generation 546 2 90 SG 6.04%55
Otr Power Generation 548 2 7,737 SG 6.048%468
cnher Power Generation 54 2 6,301 SSGCT 6.150%388
Oter Power Geration 549 2 347 SG 6.04%21
Ot Power Generation 552 2 84 SG 6.048%5
Ot Power Generation 552 2 320 SSGCT 6.150%20
cnher Poer Generation 553 2 3,886 SG 6.04%235
Oter Power Generation 553 2 920 SSGCT 6.150%57
Otr Power Generation 554 2 27 SG 6.048%2
Oter Power Generatin 554 2 280 SSGCT 6.150%17
cnher Power Supply 556 2 3,338 SG 6.048%202
Totl Annuallzation 1 434,596 26,306
Description of Adjustment:
This adjustment annualizes the O&M porton of wae increases occrrng dunng the base peno. The O&M port of wae increases
expeced dunng the 12 months after the base penod are also added. Incentive pay and employee benefis are normalized to levels the
company will incur for the 12 months ended December 2008. See page 4.9.6 for more information on how this adjustment was
calculated.
Rocky Mountain Power PAGE 4.9.1
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Annualization 2
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATEP B5
Adjustment to Expense:
Otr Power Supply 557 2 103,29 SG 6.048%6,247
Oter Power Supply 557 2 204 SSGCT 6.150%13
Transmission 560 2 17,806 SG 6.048%1,077
Transmission 561 2 17,695 SG 6.048%1,070
Transmission 562 2 1,210 SG 6.048%73
Transmission 563 2 51 SG 6.048%3
Tranmission 566 2 782 SG 6.048%47
Transmission 567 2 489 SG 6.048%30
Transmission 568 2 76 SG 6.048%5
Transmission 569 2 5,874 SG 6.048%355
Transmissin 570 2 16,716 SG 6.048%1,011
Transmission 571 2 (1,639)SG 6.048%(99)
Transmission 572 2 (0)SG 6.048%(0)
Transmission 573 2 216 SG 6.048%13
Distrbutin 580 2 18 10 Sits 3
Distrbution 580 2 59,475 SNPD 4.682%2,785
Distrbution 581 2 35,310 SNPD 4.682%1,653
Distrbuton 582 2 5,206 10 Situs 290
Distrbuon 582 2 37 SNPD 4.682%2
Distribuon 583 2 17,065 10 Situ 412
Distrbuton 583 2 1,281 SNPD 4.682%60
Distrbution 58 2 4 10 Situ
Distrbuton 585 2 979 SNPD 4.682%46
Distrbuon 586 2 11,178 10 Sit 644
Distrbutin 586 2 2,701 SNPD 4.682%126
Distrbuton 587 2 22,646 10 Situ 1,570
Distrbun 588 2 6,500 10 Situs 301
Distrbution 588 2 41,852 SNPD 4.682%1,96
Distrbutin 589 2 316 10 Situs 9
Distrbution 590 2 1,178 10 Situs 55
Distribution 590 2 21,561 SNPD 4.682%1,010
Distribut 592 2 17,431 10 Situs 728
Distrbution 592 2 7,308 SNPD 4.682%342
Distrbutin 593 2 57,325 10 Situs 5,596
Distbution 593 2 5,480 SNPD 4.682%257
Distribution 594 2 39,645 10 Situs 1,324
Distrbuton 594 2 58 SNPD 4.682%3
Distbuton 595 2 131 10 Situs
Distrbuton 595 2 1,279 SNPD 4.682%60
Distrbuon 596 2 5,192 10 Situs 380
Distributin 597 2 9,702 10 Situs 703
Distrbuton 597 2 3,489 SNPD 4.682%163
Total Annualizon 2 537,123 30,326
Description of Adjustment:
This adjustment annualizes th O&M portion of wage increases occurring during the base period. The O&M portn of wage increases
expected during the 12 months after the base perid are also added. Inctive pay and employee benefits are normalized to levels the
company will incur for the 12 month ended Deceber 2008. See page 4.9.6 for more information on how this adjustment was calculated.
Rocky Mountain Power PAGE 4.9.2
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Annualization 3
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED ~
Adjustment to Expense:
Distribution 598 2 1,637 10 Situs 31
Distribution 598 2 3,595 SNPD 4.682%168
Customer Accunting 901 2 4,962 CN 4.06%202
Customer Accounting 901 2 604 10 Situs 26
Customer Accunting 902 2 1,575 CN 4.064%64
Customer Accounting 902 2 65,240 10 Situs 3,663
Customer Accunting 903 2 95,781 CN 4.064%3,892
Customer Acunting 903 2 13,668 10 Situs 549
Customer Accunting 905 2 495 CN 4.064%20
Customer Service 907 2 910 CN 4.064%37
Customer Service 908 2 8,430 CN 4.064%34
Customer Service 908 2 8,948 10 Situs 1,073
Customer Service 909 2 1,236 CN 4.064%50
Administrtie & General 920 2 278,971 SO 5.755%16,05
Administrative & General 920 2 1,021 10 Situ
Administrative & General 922 2 (4,017)SO 5.755%(231)
Administrative & General 929 2 (1,933)SO 5.755%(111)
Administrative & General 935 2 104 10 Situs
Administrative & General 935 2 11,999 SO 5.755%691
Totl Annuallzation 3 493,224 26,523
Total Annual/zation 1
Total Annual/zation 2
Total Annualization 3
Total Wage & Employee Benefit Annualization
434,596
537,123
493,224
1,464,942
26,306
30,326
26,523
83,155
Description of Adjustment:
This adjustment annualizes the O&M portion of wage increases occurrng during the base period. The O&M portion of wage
increases expected during the 12 months after the base period are also added. Incentive pay and employee benefis are normalized
to levels the company will incur for the 12 months ended December 2008. See page 4.9.6 for more information on how this
adjustment was calculated.
Rocky Mountain Power PAGE 4.9.3
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Pro Fona 1
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED BS
Adjustment to Expense:
Steam Generation 500 3 156,824 SG 6.048%9,485
Steam Generation 501 3 7,139 SE 6.586%470
Steam Genertion 502 3 177,279 SG 6.048%10,722
Steam Generation 505 3 16,079 SG 6.048%972
Steam Generation 506 3 352,592 SG 6.048%21,325
Steam Generation 506 3 (196)SSGCH 5.731%(11 )
Steam Generation 510 3 27,616 SG 6.048%1,670
Steam Generation 511 3 69,004 SG 6.048%4,173
Steam Generation 511 3 (78)SSGCH 5.731%(4)
Steam Generation 512 3 273,726 SG 6.048%16,555
Steam Generation 512 3 (2,355)SSGCH 5.731%(135)
Steam Generation 513 3 104,227 SG 6.048%6,304
Steam Generation 513 3 6 SSGCH 5.731%0
Steam Generatin 514 3 24,178 SG 6.04%1,462
Steam Generation 514 3 (208)SSGCH 5.731%(12)
Hydro Geeration 535 3 38,979 SG-P 6.048%2,357
Hydro Generation 535 3 36,723 SG-U 6.048%2,221
Hyro Generation 536 3 403 SG-P 6.048%24
Hydro Generation 537 3 5,072 SG-P 6.048%307
Hydro Generation 537 3 917 SG-U 6.048%55
Hydro Generatin 539 3 33,845 SG-P 6.048%2,047
Hydro Generatin 539 3 34,798 SG-U 6.048%2,105
Hyro Generation 542 3 2,673 SG-P 6.048%162
Hydro Generation 542 3 707 SG-U 6.048%43
Hydro Geeration 543 3 3,420 SG-P 6.048%207
Hydro Genetion 54 3 1,886 SG-U 6.04%114
Hyro Geertion 54 3 7,819 SG-P 6.048%473
Hyro Geeratin 544 3 2,686 SG-U 6.048%162
Hydro Generation 545 3 3,681 SG-P 6.048%223
Hyro Generation 545 3 1,612 SG-U 6.04%97
Other Power Generation 54 3 3,048 SG 6.048%184
Other Power Generation 548 3 26,035 SG 6.048%1,575
Otr Por Generation 548 3 21,201 SSGCT 6.150%1,304
Other Power Generation 549 3 1,168 SG 6.048%71
Othe Power Generatin 552 3 284 SG 6.048%17
Other Power Generation 552 3 1,078 SSGCT 6.150%66
Otr Power Generation 553 3 13,076 SG 6.048%791
Oter Powr Generatin 553 3 3,094 SSGCT 6.150%190
Oter Powr Generation 554 3 90 SG 6.048%5
Other Powe Generatin 554 3 944 SSGCT 6.150%58
Other Power Supply 556 3 11,231 SG 6.048%679
Total Pro Fonna 1 1,462,302 88,514
Description of Adjustment:
This adjustent annualizes the O&M portion of wage increases occurnng during the base period. The O&M portion of wage
incrases expected during the 12 moths after the base period are also added. Incentive pay and employee benefits are normalized
to levels the company will incur for the 12 month ended December 2008. See page 4.9.6 for more information on how this
adjustment was calculated.
Rocky Mountain Power PAGE 4.9.4
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Pro Forma 2
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCAED B&
Adjustment to Expense:
Other Power Supply 557 3 347,565 SG 6.048%21,021
Other Por Supply 557 3 688 SSGCT 6.150%42
Transmission 560 3 59,912 SG 6.048%3,623
Transmission 561 3 59,54 SG 6.048%3,601
Transmission 562 3 4,071 SG 6.048%246
Transmission 563 3 172 SG 6.048%10
Transmission 56 3 2,630 SG 6.048%159
Transmission 567 3 1,645 SG 6.048%99
Transmission 568 3 257 SG 6.048%16
Transmission 569 3 19,764 SG 6.04%1,195
Transmission 570 3 56,245 SG 6.048%3,402
Transmission 571 3 (5,516)SG 6.048%(33)
Transmission 572 3 (0)SG 6.04%(0)
Transmission 573 3 726 SG 6.048%44
Distrbution 580 3 59 10 Situs 9
Distnbuton 580 3 200,119 SNPD 4.682%9,370
Distbution 581 3 118,810 SNPD 4.682%5,563
Distrbution 582 3 17,516 10 Situs 976
Distrbution 582 3 125 SNPD 4.682%6
Distrbution 583 3 57,421 10 Situ 1,387
Distnbution 583 3 4,30 SNPD 4.6820k 202
Distnbution 58 3 14 10 Situs
Distnbution 585 3 3,294 SNPD 4.682%154
Distrbution 586 3 37,611 10 Sits 2,167
Distrbution 586 3 9,088 SNPD 4.682%426
Distrbuon 587 3 76,198 10 Situ 5,282
Distrbution 588 3 21,870 10 Situs 1,014
Distrbutin 588 3 140,82 SNPD 4.682%6,594
Distnbution 589 3 1,06 10 Situs 30
Distrbution 590 3 3,96 10 Situs 185
Distrbution 590 3 72,547 SNPD 4.682%3,397
Distrbuon 592 3 58,851 10 Situ 2,450
Distnbution 592 3 24,590 SNPD 4.682% .1,151
Distnbutin 593 3 192,885 10 Situ 18,829
Distrbuton 593 3 18,43 SNPD 4.682%863
Distrbuton 594 3 133,397 10 Situs 4,455
Distrbutin 594 3 195 SNPD 4.682%9
Distrbutn 595 3 44 10 Situs
Distnbuton 595 3 4,30 SNPD 4.6820/0 202
Distnbuon 596 3 17,471 10 Situs 1,279
Distrbutin 597 3 32,645 10 Situs 2,364
Distnbution 597 3 11,741 SNPD 4.682%550
Tota Pro Forma 2 1,807,281 102,040
Description of Adjustment:
This adjustment annualizes the O&M portion of wage incrases occurnng dunng the base penod. The O&M porton of wae incrases
expected dunng the 12 months after the base penod are also added. Incentive pay and employee benefits are normalized to levels the
company wil incur for the 12 months ended Decmber 2008. See page 4.9.6 for more information on how this adjustment was
calculated.
.
Rocky Mountain Power PAGE 4.9.5
Idaho General Rate Case. December 2007
Wage & Employee Benefits. Pro Fora 3
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED BW
Adjustment to Expense:
Distribution 598 3 5,507 10 Situs 105
Distnbution 598 3 12,095 SNPD 4.682%566
Customer Accunting 901 3 16,697 CN 4.064%679
Customer Accunting 901 3 2,032 10 Situs 89
Customer Accunting 902 3 5,299 CN 4.06%215
Customer Accunting 902 3 219,516 10 Situ 12,324
Customer Accunting 903 3 322,277 CN 4.06%13,097
Customer Accunting 903 3 45,988 10 Situs 1,846
Customer Acunting 905 3 1,666 CN 4.06%68
Customer Servce 907 3 3,061 CN 4.064%124
Customer Seice 908 3 28,363 CN 4.064%1,153
Customer Service 908 3 30,109 10 Situs 3.612
Customer Service 909 3 4,159 CN 4.064%169
Administrtive & General 920 3 938.667 SO 5.755%54,025
Administrti & General 920 3 3,434 10 Sits
Administrtie & General 922 3 (13,517)SO 5.755%(778)
Administrtive & General 929 3 (6.506)SO 5.755%(374)
Adminitrative & General 935 3 35 10 Situs
Administrative & General 935 3 40,372 SO 5.755%2.324
Tot Pro Fonna 3 1,659.570 89,242
Total Pro Fora 1
Totl Pro Fonna 2
Total Pro Fonna 3
Total Wage & Employee Benefit Pro Fonna
1,462,302
1,807,281
1,659,570
4,929,154
88,514
102,04
89,242
279,796
Description of Adjustment:
This adjustment annualizes the O&M portn of wage increases occrnng during the base period. The O&M portion of wage
increases expected during the 12 months after the base period are also added. Incentive pay and employee benefits are normalized
to levels the company will incur for the 12 months ended December 2008. See pag 4.9.6 for more information on how this
adjustment was calculated.
Rocky Mountain Power
Idaho General Rate Case - December 2007
Wage and Employee Benefit Adjustment
The base period, annualized, and the proforma labor expenses are summarized on page 4.9.7.
The following is an explanation of the procedures used to develop annualized and pro forma
labor expenses.
1. Actual December 2007 total labor related expenses are identified on page 4.9.7, including bare
labor, incentive, other labor, pensions, benefits, and payroll taxes.
2. Actual December 2007 expenses for regular time, overtime, and premium pay were identified by
labor group and annualized to reflect wage increases during the base period. These annualizations
can be found on pages 4.9.8 - 4.9.9.
3. The annualized December 2007 regular time, overtime, and premium pay expenses were then
escalated prospectively by labor group to December 2008 (see page 4.9.9.). Costs were escalated
using the rates found on page 4.9.10.
4. Non-union incentive payments were provided by the Human Resources department and were
calculated based on the calendar year 2008 projections. Union employees do not participate in the
Company's annual incentive program; instead, they receive annual increases to their wages that are
reflected in the escalation described above.
5. Proforma December 2008 pension and employee benefits expenses were provided by the Human
Resource department. These expenses can be found on page 4.9.12. Payroll tax calculations
can be found on page 4.9.13, along with the wage amounts used in the calculation.
Page 4.9.6
Rocky Mountain Power
Idaho General Rate Case. Dember 2007
Wage & Employee Benefit Adjustment
, " .,i;~.~_:~w,'~~"t~.~, ,
';'-,--,
501 XX5O50XX
50110
50XX5050
50109X
Annualiz
. ";'"""'-"",'.-.-'-,,,
12MóilEía8c.1)b82l7
38.93.936 388.56.26
58.002.316 58.247.457
5,50.802 552405
45,434,054 452337,771
739.293 742.418
1.03.430 1.04.823
7.971.169 7.971.169
/1 .239.895)1245135
458,944.051 460,850,045
29.875.94 29875948
29,875,948 29,875,948
93.392 932.392
3.64.35 3.64.355
122.169 122.169
2.082 2.082
34.588 34.588
/43.128)43128
5,010,458 5,010,458
493,830,45 495,736.450
47.272.772 47.272.772
7.89.56 7.896.56
4.128.73 4.128.73
25.90.110 25.903.110
4,918.126 4918126
90,119,309 90119,309
926.312 926.312
45.625.67 45.625.678
2,857.882 2.857.882
52.198 529.198
1.180.752 1.180.752
18.20.798 18.20.79
1.734.461 1.73.461
61.992 61.99
7.22.951 7.222.951
2.90.513 2.90.513
1,266.565 1266 565
82,522,101 82,522,101
172,641,410 172.641.410
32.84.762 32.979.774
2.751.891 2.751.891
141 141
35,600,794 35,731,806
702,072,660 704,109.666
197.167.159 197.739.223
50,9õ5,501 50 ,3 0,443
;.' L::",).:.':t-
, ;'~:;'d;' ;". ,~:- :"i,::-:-
RlI Orrv TÎ
OvermePriuPav
Subttal for Escalation
Se Lab AdjusmeUn Leav Ac
Oth SalLabo CostsJOCuts
Subtotal Bare Labor
5O inc
Tota Incentive
502505070
501103
50132550235899
Ovim MesSeedan (1)Jo Ow Poon PayentPhy ExEdu Astanc
Ml SalarlB_Iil Cr
Tot Oter Labor
Subtotal Labor and Incentive
501100
501105
501115
501150
501160
501102
50112X
501175
501200
50122X
501250
501251
501275
50130
5016XX50
Pen. FAS 87
Pen - IBEW 57 . FAS 87
SERPPIa
Po Reten Beit . FAS H16
pO! Emplen Bents. FAS 112
Totl Pensions
Pen Adtr. MeDeVi
LifeSt01(k)ISOP
401(k) Aiti
Acc Deh & Disabi. Tenn DisWOeis Comnsat
Othe Salary OveiadTota Benefits
Subtotal pensions and Benefi
580
587005800
Pay Tax ExePav Tax ExUnpl
Othe Pay Taxes
Tota Payrll Taxes
Total Labor
NoUt an Capali Lab
Total Utlity Labor
Nos:
(1) No adtmen is ma to se ti it is co in Ih MEHC Tra Adjutment
Pag 4,9.7
245.141
23249
1,903717
Profona
~" .';.
.1i..¿~~êná~~''f.:... .....t..
.:. oK2OO8 ;.........c:'......."."..'"..-.".._....f
399.065.09 .... GO:4.9.1
59.821.269 1.573.812 4.9.1
5673307 149257 4.9.
46.559.670 12.221.899
782.477 20.06 4.9.11
1.072.026 28.203 4.9.11
7.971.169
11 278776 133643\4.9,11
473,086,564 12,236,519
3079505 914557 4.9.11
30,790.505 914,557
932.392 .
3.646.355 -
122.169 .
2.082 .
34.588 -
143128 .
5,010.458 .
508,887527 13.151,017
35.314.56 (11.95.20)4.9.12
8.66.276 768.70 4.9.12
2.60.00 (1.528,733)4.9.12
24.553.246 (1.34.86)4.9.12
8024686 3106560 4.9.12
79,157,172 110.961,5371 4.9.12
96.671 37.35 4.9.12
50.216,993 4.591.316 4.9.12
2.05.221 (802.66)4.9.12
229.410 (299.788)4.9.12
1.152.207 (28.54)4.9.12
23.137.23 4.93.43 4.9.12
33.194 (1.39.267)4.9.12
72.00 10.016 4.9.12
3.38.589 (3.859.38)4.9.12
3.092.113 182.59 4.9.12
1659397 392832 4.9.12
86,278,037 3.755,936 4.9.12
165,435.809 7.205.601)U.12
33.888.302 90.528 4.9.13
2.751.891 .
141 .
36,640.334 908528
710,963.670 6,854.004 4.11.17
199.664.073 1.924.850 4.11.17
511.299.597 4.929,154 4.11.7
3.125
4.393
5240
1905,994
1,905,994
131.013
131,013
2,037.007
572.06
1,464.942
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Rocky Mountain Power
Idaho General Rate Case. December 2007
Wage and Employee Benefit Adjustment
Composite Labor Increases
Regular Tun/Ovrte/Preium Pay Der 2007
Totl Anualed Debe 2007Inc
Tota Pr Form Deember 200
Inaeas
Miscellaneous Bare Labor Escalation
Acunt
500110
5O5X
50109X
Deber 2007 Actals
739,293
1,039,430
(1,239,895)
538,828
Annual Incentive Escalation
Acunt505010
5OXX
Deber 2007 Actals
1,222,460
28,653,487
29,875,948
Incrse
0.42%
0.2%
0.42%
450,434,054
452,337,ni
0.42%
46,559,670
2.70%
Deceber 2007
Annualized
742,418
1,043,823
(1,245,135)
541,105
Inc
2.70%
2.70%
2.70%
Deber 2007
ProFonna
762,477
1,072,026
(1,278,778)
555,726
Deber 2008But
30,790,505
Pag 4.9.11
Refnc
4.9.7
4.9.7
4.9.7
Re
4.9.7
4.9.7
4.9.7
4.9.7
Rocky Mountain Power
Idaho General Rate Case. December 2007
Wage and Employee Benefits Adjustment
Employee Pension and Benefits Summary
501100
501105
SOii5
SOl1SO
S01160
S01102
SOl12X
S01175
S01200
S0122X
S0125
501251
S01275
SOl30
S016XXS029
Pensn - FAS 87
Pens - ISE 57 - FAS 87
SERP Plan
Po Rerement Benefi - FAS 106
Po Employmt Beefts - FAS 112
Subttal
Penn AdistionMeicDeta
VISon
ute
St401(k)/ESO
401(k) AdministonAcnta De & Disability
Lo-Tei DiilitWorers Consaon
Oter salary OvereadSUbt
Grand Total
47,2n,n2
7,896,568
4,128,733
25,903,110
4,918,126
90,119,309
926,312
45,625,678
2,85,882
529,198
1,180,752
18,206,798
1,73,461
61,992
7,222,951
2,90,513
1,266,565
82,522,101
172,641,410
49,127,34 36,700,00 35,314,564
7,896,568 8,665,276 8,665,276
4,128,733 2,60,00 2,60,00
26,690,919 25,300,00 24,553,246
5,067,706 8,268,750 8,024,686
92,911,270 81,534,026 79,157,772
950,563 988,90 963,671
47,083,032 51,821,001 SO,216,993
2,972,127 2,137,38 2,055,221
552,40 239,472 229,410
1,215,54 1,186,154 1,152,207
18,817,619 23,913,466 23,137,23
1,786,473 34,276 336,194
61,992 72,008 72,008
7,329,988 3,413,434 3,363,589
2,993,60 3,181,485 3,092,113
1,268,393 1,661,793 1,659,397
85,031,743 88,961,369 86,278,037
177,943,014 170,495,395 165,435,809
E -A
:."~:~o~~;:'i';
Adustent: "''':'~~;;':~:;';"';-/.~':::;- .'
(11,958,208)
768,708
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(1,349,865)
3,106,560
(10,961,537)
37,359
4,591,316
(802,660)
(299,788)
(28,545)
4,930,436
(1,39,267)
10,016
(3,859,362)
182,599
392,832
3,755,936
(7,205,601) 4.9.7
Pag 4.9.12
"'-:.:-::-:-i3"...
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4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9,7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
4.9.7
Pag 4.9.13
Rocky Mountain Power
Idaho General Rate Case - December 2007
Wage and Employee Benefit Adjustment
Payroll Tax Adjustment Calculation
FICA Calculated on Annualized CY 2007 Labor Reference
Annualized Wages Adjustent 1,905,994 4.9.7
Annualized Incentive Adjustenti Totl Annualized Wage Increase Adjustment 1,905,994
Medicare Rate (no cap)1.45%
27,637
Soal Serity Rate 6.20%
118,172
Percentage of Soial seurity Ellgible Wages 87.48%
103,376
Total FICA Tax 131,013 4.9.7
FICA calculated on Pro Forma CY 2008 Labor
Pro Forma Wages Adjustment 12,236,519 4.9.7
Pro Forma Incentive Adjustment 914,557 4.9.7
Total Pro Forma Wag Increase Adjustment 13,151,077
Medicare Rate (no cap)1.45%
190,691
Soial Serity Rate 6.20%
815,367
Percntae of Soial Serity ElIlgible Wage 88.04%
717,837
Total FICA Tax 908,528 4.9.7
Rocky Mountain Power
Idaho General Rate Case - Decembe 2007
Wage and Employee Benefit Adjustment
Adjustment by FERC Account and Revised Protocol Factor
50
501
502
505
50
510
511
512
513
514
535
536
537
539
542
543
54
545
546
548
549
552
553
554
556
557
56
561
562
56356
567
568
569
570
571
572
573
580
581
582
SG
SE
SG
SG
SG
SSGCH
SG
SG
SSGCH
SG
SSGCH
SG
SSGCH
SG
SSGCH
SG-P
SG-U
SG-P
SG-P
SG-U
SG-P
SG-U
SG-P
SG-U
SG-P
SG-U
SG-P
SG-U
SG-P
SG-U
SG
SG
SSGCT
SG
SG
SSGCT
SG
SSGCT
SG
SSGCT
SG
SG
SSGCT
SG
SG
SG
SG
SG
SG
SG
SG
SG
SG
SG
SG
LOU
SNPO
WYP
SNPO
CA
LOU
OR
SNPO
UT
Actl.
16.063.824
731.264
18.159,166
1.646.986
36.116,921
120,032
2828,771
7.068,259
18.031
28.038.458
(241.215
10.676,192
578
2.476,578
121.321
3.992,740
3761,634
41,330
519,512
93964
3,466,809
3.564,442
273,780
72,380
350.278
193,187
800,96
275110
377,078
165.109
312.219
2.66.799
2.171.66
119673
29.099
110,412
1.339.397
318.937
9.218
96.677
1,150.448
35.601.958
70.436
6.136.950
6,098.781
417.034
17.653
269.372
168.493
26.275
2.024,470
5.761.307
(56.966)
(0)
74356
885
20,498,638
5.208
12.169.973
48.385
99.961
668.731
12.755
633,871
Annualized;r '1t~.~_ \sl;;:/,
,~, 4~:;W~ 16.110432.'. ., "1æ.8242 122 733 386 7 139
52.687 18,211.853 177.2794.779 1,651.765 16.079
104.790 36,221.712 352.592(58 . 120.090 11968207 2.836.978 27,616
20.508 7,088.767 69.004(23 18,054 . 178
81.351 28,119.809 273,7261700 l241.915 12.355
30,976 10,707.168 104,2272 560 67,186 2.483.763 24,178162 .121.383 1208
11,585 4,004.324 38,97910,914 3.772.548 36,723120 41.450 4031.507 521,019 5,072273 94 237 91710.059 3.476.868 33,64510342 3.574764 34.798794 274.574 2.673210 72.590 7071.016 351.294 3.420561 193.748 1,8862.324 803.288 7,819798 275.908 2,6861.094 378.172 3.681479 165.588 1,61290 313.124 3048
7.737 2.674.536 26,0356301 2.177.961 21.201347 120.020 1,16884 29,184 284320 110,732 1,078
3.886 1.343.28 13.076920 317,857 3.09427 9.245 90280 96,957 943,338 1.153,786 11.231
103.296 35,705,254 347.56520 70,641 68817.806 6,154,756 59.91217.695 6.116.476 59.5401.210 418.244 4.07151 17.705 172782 270.153 2.630489 168.982 1.64576 26,352 2575,874 2,030.34 19.764
16.716 5.778,023 56.245
(1.639) (566,625) (5.516)(0) (0) (0)216 74,572 7263 888 9
59,475 20.558.113 200.11915 5.223 51
35.310 12.205,283 118.810140 48.525 472290 100,251 9761.940 670,671 6.52937 12,792 1251,839 635.710 6,188
2.3%
0.1%
2.6%
0.2%
5.1%
0.0%
0.4%
1.0%
0.0%
4.0%
0.0%
1.5%
0.0%
0.4%
0.0%
0.6%
0.5%
0.0%
0.1%
0.0%
0.5%
0.5%
0.0%
0.0%
0.0%
0.0%
0.1%
0.0%
0.1%
0.0%
0.0%
0.4%
0.3%
0.0%
0.0%
0.0%
0.2%
0.0%
0.0%
0.0%
0.2%
5.1%
0.0%
0.9%
0.9%
0.1%
0.0%
0.0%
0.0%
0.0%
0.3%
0.8%
-0.1%
0.0%
0.0%
0.0%
2.9%
0.0%
1.7%
0.0%
0.0%
0.1%
0.0%
0.1%
Pag 4.9.14
ProFon
. : ~:å;:.'
16267.256
740.525
18,389.132
1,667.844
36,574.304
120.285
286594
7.157.771
18.133
28.393,535
1244,269
10.811,394
585
2.507.941
121591
4.043,304
3.809,271
41,854
52$,091
95,154
3,510,712
360,582
277.247
73.297
354,714
195,634
811.107
278.594
381.853
167,200
316.172
2.700.571
2,199.162
121.188
29.468
111,810
1,356.360
320.951
9,335
97.901
1,165,018
38.052.819
71.328
6,214.668
6,176.016
422.315
17,877
272,783
170,626
26.608
2.050.107
5.834,268
(572.141)
(0)
75,298
897
20.758.231
5.274
12,324093
48.998
101.227
677.199
12.917
641,698
Page 4.11.15
Rocky Mountain Power
Idaho General Rate Case - December 2007
Wage and Employee Benefit Adjustment
Adjustment by FERC Account and Revised Protocol Factor
-Annualized Pro Fonna I~'.....,...... ,: X:èi"'Y:'ÂJ~~~¡iâû~. .'.",',.,:..c;...1,.0 i= ..........:1....';:.....
.,5òfTot.,. . .. . ... . '.-:.(;',.'.f':¡¡'~;;i;%J:f'£~~~(J :.;~¡~~.".........
.~122.240 0.0% 355 1:i2.5115 1,193 1: 3.88
WYP 221018 0.0%641 221.659 2,158 223.817
583 CA 312,285 0.0%906 313.191 3.049 316,240
LOU 142.110 0.0%412 142,522 1.387 143,90
OR 2.053,410 0.3%5.958 2.059.36 20.046 2.079,414
SNPO 441,352 0.1%1.281 442.832 4.309 446.941
UT 2.495,959 0.4%7.242 2.503.201 24,367 2,527.568
WA 316,no 0.0%919 317,689 3.092 320.782
WYP 401,144 0.1%1.164 402.308 3,916 406.224
WYU 160046 0.0%464 160.510 1,562 162.073
584 CA 0 0.0%0 0 0 0
OR 0 0.0%0 0 0 0
UT .0.0%.-..
WA 1.408 0.0%4 1,412 14 1.426
WYP (0 0.0%10 (0 10 (0
585 SNPO 337398 0.0%979 338.3n 3.294 341,671
58 CA 160.594 0.0%46 161.060 1,568 162.627
LOU 22.011 0.0%644 222.655 2.167 224.822
OR 1.534.974 0.2%4.454 1.539.427 14,985 1.5.54.413
SNPO 930.94 0.1%2.701 933,647 9.08 942.736
UT 1.063.883 0.2%3.067 1.066.970 10.386 1.077,356
WA 50.690 0.1%1.479 511,169 4,976 516.145
WYP 323.271 0.0%938 324.20 3.156 327.365
WYU 38.212 0.0%111 38.323 373 38.696
587 CA 494,368 0.1%1.434 495.803 4.826 500.629
IOU 541.00 0.1%1.570 542.576 5,282 547,857
OR 3.067,901 0.4%8.901 3.076.80 29.950 3.106.753
UT 2.504.705 0.4%7.267 2.511.973 24.452 2.53.425
WA 654.726 0.1%1.90 656.625 6.392 863.017
wyp 484.894 0.1%1.407 486,301 4.734 491.034
WYU 57.511 0.0%167 57.678 561 58,240
588 CA 33.862 0.0%98 33.96 331 34,291
LOU 103.908 0.0%301 104.209 1.014 105.224
OR 797.653 0.1%2.314 799.967 7.787 807.754
SNPO 14.424.570 2.1%41.852 14.466.422 140,820 14.607.242
UT 1,020.397 0.1%2.961 1.023.358 9.962 1,033.319
WA 116.355 0.0%338 116,693 1,136 117.829
WYP 148,234 0.0%430 148.66 1.447 150.111
WYU 19.753 0.0%57 19.810 193 20.003
589 CA 5,046 0.0%15 5.061 49 5.110
LOU 3.022 0.0%9 3.031 30 3.060
OR 42.731 0.0%124 42.855 417 43.272
UT 21.588 0.0%63 21.650 211 21.861
WA 2.831 0.0%8 2.839 28 2,867
wyp 29,721 0.0%86 29.807 290 30.097
WYU 4,026 0.0%12 4038 39 40n
590 CA 25.029 0.0%73 25.101 244 25.346
IOU 18.961 0.0%55 19.016 185 19.201
OR 165.66 0.0%481 166.145 1.617 161.762
SNPO 7.431.147 1.1%21.561 7.452.708 72.547 7.525.255
UT 119.421 0.0%346 119.768 1.166 120.934
WA 9.486 0.0%27 9.494 92 9.58
wyp 67,463 0.0%196 67.659 659 68.318
592 CA 294.173 0.0%854 295.026 2.872 297.898
LOU 250.99 0.0%728 251.726 2,450 254.177
OR 2.23.243 0.3%6,482 2.240.726 21.812 2.262.537
SNPO 2.518.823 0.4%7,308 2.526.131 24.590 2.550.721
UT 2.033,274 0.3%5.899 2.039.173 19.850 2.059.023
WA 406.610 0.1%1.180 407.790 3.970 411.759
wyp 188.272 0.1%2.287 790.559 7.696 798.255
WYU 199 0.0%1 199 2 201
593 CA 1.943.367 0.3%5,639 1.949,006 18.972 1.967.978
IOU 1.928.674 0.3%5.596 1.934,270 18,829 1.953.098
OR 8.951.35 1.3%25.972 8.977,327 87.388 9.06.715
Rocky Mountain Power
Idaho General Rate Case. Deember 2007
Wage and Employee Benefit Adjustment
Adjustment by FERC Account and Revised Protocol Factor
594
SNPO
UT
WA
WYP
WYU
CA
LOU
OR
SNPO
UT
WA
WYP
WYU
OR
SNPO
UT
WYP
CA
lOU
OR
UT
WA
WYP
WYU
CA
LOU
OR
SNPO
UT
WA
WYP
WYU
CA
LOU
OR
SNPO
UT
WA
WYP
WYU
CA
CN
LOU
OR
UT
WA
WYP
WYU
CA
CN
LOU
OR
UT
WA
WYP
WYU
CA
CN
LOU
OR
UT
WA
WYP
WYU
595
596
597
598
901
902
90
1.888.684
4.123.764
1.207.147
1.419.428
183.952
685.267
456.370
3.665.279
19.983
7.209.811
668.425
824.845
154.140
39.497
44.865
5.528
84.711
131.05
717.529
417.845
169.983
209.307
59.152
43.671
242.149
913.90
1.202.642
1,331.846
314.692
439.331
58333
18.20
10.746
89.942
1.238.910
387.907
43.907
6.693672
2.624
1.710.301
9.100
66.526
53.747
52.187
9.973
11979
721.166
542.745
1.26,357
7.44,592
9.301.017
1.695.807
1.816.324
244.342
195.96
33.011.656
189.124
1.66.303
2,027.436
375.26
209.84
47.735
Pag 4.9.16
l\;;a¿
0.3% 5.4800.6% 11.9650.2% 3.5020.2% 4.1180.% 5340.1% 1.9880.1% 1.3240.5% 10.6350.0% 581.0% 20.9190.1% 1.9390.1% 2.3930.0% 4470.0% 1150.1% 1.2790.0% 16
0.0%
0.0%
0.0%
0.1%
0.1%
0.0%
0.0%
0.0%
0.0%
0.0%
0.1%
0.2%
0.2%
0.0%
0.1%
0.0%
0:0%
0.0%
0.0%
0.2%
0.1%
0.0%
0.0%
0.0%
0.0%
0.2%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.1%
0.1%
0.2%
1.1%
1.3%
0.2%
0.3%
0.0%
0.0%
4.7%
0.0%
0.2%
0.3%
0.1%
0.0%
0.0%
246
380
2.082
1.212
493
807
172
127
703
2.652
3.4893.86
913
1.275
169
53
31
261
3.595
1.125
127
19
20
8
4.962
26
199
156
151
29
35
2.092
1.575
3.663
21.60
26.98
4.920
5.270
709
569
95.781
549
4.832
5.882
1,08960
138
. '~'ÀÉ,ii¡;.?,1.894.164 18.438
4.135.728 40.258
1.210.649 11.785
1.423.546 13.857
184.485 1.796
687.256 6.690
457.694 4.455
3.675.913 35.78220.041 195
7.230.729 70.386670.365 6.526
827.238 8.053
154.587 1 50539.612 386442.144 4.305.54 54
84.957
131.431
719.611
419.058
170.476
209.914
59.323
43.797
242.851
916.559
1.20.132
1.335.710
315.605
440.606
58.502
18.257
10.778
90.203
1.242.505
389.033
44.035
6.713
6.741
2.632
1.715.263
9.126
68.725
53.903
52.338
10.002
12.014
723.258
54.320
1.26.020
7.466.192
9.328.003
1.700.72
1.821.594
245.051
196.532
33.107.436
189.672
1.670.135
2.033.318
376.349
210.452
47.873
827
1.279
7.005
4.079
1.659
2.043
577
426
2.364
8.922
11.741
13.002
3.072
4.289
569
178
105
878
12.095
3.787
429
65
86
26
16.697
89
869
525
509
97
117
7.040
5.299
12.324
72.678
90.801
16.555
17,732
2.385
1.13
322.277
1.84
16.258
19.793
3.663
2.049
466
208
.,t),t;i,'j;)(
1.912.602
4.175.987
1.222.434
1.437.403
186.281
693.945
462.149
3.711.696
20.236
7,301.115
676.890
835.291
156.092
39.997
44.448
5.598
85.784
132.710
726.616
423.137
172.136
211.958
59.901
44.224
245.215
925.481
1.217.873
1.348.712
318.677
444.895
59.072
18.434
10.882
91.081
1.254.60
392.820
44.463
6.778
6,807
2.657
1.731.960
9.215
69.394
54.428
52.848
10,09
12.131
730.299
549.619
1.278.343
7.538.870
9.418.804
1,717.283
1.839.326
247,437
198.445
33.429.714
191.519
1.686.393
2.053.111
380.013
212.500
48,339
Rocky Mountain Power
Idaho Gene Rate Case. December 2007
Wage and Employee Benefit Adjustment
Adjustment by FERC Account and Revised Protocol Factor
I . I "'li.'.
i.~-, 7,~7-':~~ cd
1105
907
908
Noulilty
Capita
Searv Labo
Totl Labo
909
920
922
929
935
uti Labo
Nollt and Capil
:N
CN
CA
CN
iOU
OR
UT
WA
wyp
CN
SO
WA
wyp
SO
SO
OR
SO
Ac.ia
.:..L:j/i0f' 'd;.; ....%.of.Totd; .,'ic':T,',;;:¡:
170,681 0.0%
313.537 0.0%
4,363 0.0%
2.905.322 0.4%
369,963 0.1%
1,099.153 0.2%
950.29 0.1%o 0.0%.
660386 0.1%
426007 0.1%
96.149,966 13.7%
358.43 0.1%
(6.643 0.0%
(1.38.598) -0.2%
(666,397 -0.1%
35.882 0.0%
4 135.447 0.6%
2.422.117 0.3%
194.543.029 27.7%
202.013 0.0%
702,072,659 100%
197,167,169 28.8%
71.2%60,906,501
R.f4.9.7
~~i~~¡f~~~;
495
910
13
8.430
1.073
3.189
2.757
o
1916
1236
276,971
1.04
(19
(4.017)(1933
104
11,999
7,028
56.451
586
2,037,007
672,064
1,46,942
Ref 4.9.
Anualized
.; :'T
.;.:'..;'.,.,.,.... .)":(c;;
71.1'76
314.44
4.375
2.913.752
371.037
1.102.342
953.049
o
662.302
427.243
96.428,937
359.478
(6,663
(1,388.615)
(668.330
35.986
4147.446
2.429.145
195.107.479
202599
704,109,666
197,739,223
506,370,44
R.f4.9.7
Pag 4.9.17
ProForma
.PiFomi. . y:;;,/',:.;...':';: Bi..;-i...: .. ... .. .... ,.\:. .'¡~ua~~t; c;;:,i;)...'.. 1.66 17 !,8433.61 317,50743 4.418
28.363 2.942,1153.612 374.648
10.731 1.113.0729.277 962,326o 0
6.447 668.7494.159 431.402
938,667 97,367.6043.499 362.978(65 (6,728\
(13,517) (1.402,133). (6,506 (674,836350 36.33640.372 4187,818
23.646 2.452.791
1.899.232 197,006;7111,972 204 572
6,654,004 710,963.670
1,924,850 199,66,073
4,929,154
R.f4.9.7
611,299,597
R.f4.9.7
Description of Adjustment:
The Company eliminated many positions as a result of the MEHC transaction. These savings were made possible by the payment of
Change-In-Contrl Severance. This adjustment defers the severance cost as authonzed by the Commission in Docket No. PAe-E-Q6-11.
It is being amortized into expense over a three-year period on the boks of the Company as authonzed by the Commission in Docket No.
PAC-E-Q7-QS. This adjustment reflect the amortization on a pro fora CY 2008 basis. This adjustment also reflects the future savings of
eliminating th positons. Amounts paid to employees leaving under this proram are removed (this reval includes wage increases in
the WEBA adjustment).
Pag 4.10.1
Rcoky Mountain Power
Idaho General Rate Case - Dember 2007
MEHC Transition Savings
Recap of Costs
Severance SERP Total Ref
Dec-05 461,871 461,871
Jan-06 621,839 621,839
Feb-06 541,855 541,855
Mar-06 9,091,098 1,211,600 10,302,698
Apr-06 2,442,461 987,700 3,430,161
May-06 1,654,407 1,654,407
Jun-06 3,787,684 289,000 4,076,684
Jul-o 752,698 752,698
Aug-06 5,429,173 75,000 5,504,173
5ep-06 8,353,838 240,000 8,593,838
Oct-06 2,932,641 2,932,641
Nov-06 3,434,349 435,000 3,869,349
Dec-06 515,787 686,713 1,202,500
Prior to Test Perio 40,019,701 3,925,013 43,944,714
Jan-07 309,965 309,965
Feb-07 2,174,847 2,174,847
Mar-07 2,074,000 2,074,000
Apr-07 1,209,523 1,209,523
May-07 1,718,413 1,718,413
Jun-07 18,419 18,419
Jui-07 (110,574)(110,574)
Aug-07 (7,345)(7,345)
Sep-7 (142,448)(142,448)
Qc-07 (659)(659)
Nov-07 (10,501)(10,501)
Dec-07 (138,007)(138,007)
Remove from Results 7,095,634 7,095,634 Ref 4.10
Washington Reg Asset Set-Up in June 2007
Account Factor Amount
Leave in Results 182.399 WA 1,911,142
Remove from Results 920 SO (1,911,142)Ref 4.10
Idaho Reg Asset Set-Up in December 2007
Accont Factor Amount
182.399 NUTIL 1,830,583
Remove from Results 920 SO (1,830,583)Ref 4.10
Amortization of deferred CIC severance 610,246 Ref 4.10
Rcoky Mountain Power
Idaho General Rate Case - December 2007
MEHC Transition Savings
Savings from MEHC Change-in-Control Severance
Remove Pay from Base Period*
Org Unit Total Amount
Generation 328,598C&T 56,049Rocky Mt. Power 5,882
Rocky Mt. Power 20,989Rocky Mt. Power 3,189Pacific Power 231,122
Pacc Power 534,455IT 1,002,244
Cororate 553,517
Grand Total 2,736,047
Summary of Charges by Account557 358,359 4.10
560 182,552 4.10580 427,507 4.10903 19,150 4.10
920 1,151,305 4.10
2,138,874 4.10
Expense %
92.0%
100.0%
91.2%
91.2%
91.2%
79.0%
79.0%
59.4%
100.0%
Expense Amt.
302,311
56,049
5,367
19,150
2,909
182,552
422,141
594,878
553,517
2,138,874
Pag 4.10.3
Acct
557
557
580
903
920
560
580
920
920
*These amounts paid have been escalated and so should be removed from results after escalation as a
tye 3 adjustment.
Rocky Mountain Power
Idaho General Rate Case. December 2007
Incremental Genration O&M
PAGE 4.11
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR Of ALLOCATED BW
Adjustment to Expense:
Lake Side and Chehalis 549 3 12,773,567 SG 6.048%7n,537
Blundell Bottmin Cycle 549 3 489,987 SG 6.048%29,634
Marengo 549 3 3,009,616 SG 6.04%182,020
Mareo II 549 3 2,320,617 SG 6.048%140,349
Goodnoe Hils 549 3 2,457,997 SG 6.048%148,658
Oren Energy Trust Fun Creit 549 3 (2,450,697)SG 6.048%(148,217)
Administrtion 549 3 710,211 SG 6.048%42,953
19,311,298 1,167,935 4.11.1
Descnptlon of Adjustment:
This adjustment adds incmental operation and maintenance expense for the Lake Side plant, Blundell bottoming cycle, and the
Mareno wind plant which were placed into service September 2007, December 2007, and August 2007 respectively. This
adjustment also adds incemental operation and maintenance expenses for generating units that were not in service during the 12
months ended Decmber 2007 but wil be in service during the 12 months ended December 2008.
Rocky Mountan Power
Idaho Genel Rat Case Dember 207
Incrementa Geneon O&M
Lake Sid and Chehalis
Blunde" Botomin C)
Maro
Marego II
GonoHiIs
Oreg Eny Tru Fu Cr.
Adtrtion
Total:
Mont in Test Peri
12
12
12
12
12
12
12
Jan. . Des, 207
1.845.288
20.013
1.883.25
o
o
o
76.639
3.825.197
Amount in Test Period
14.618.855
510.00
4.892.873
2.320.617
2.457.997
(2.45.697)
78.85
23.136.494
Variance
12.n3.567
48.987
3,09.616
2.320.617
2.45.997
(2.45.697)
710.211
19,311,29 Ref 4.11
. The crts wi" be ap against th opra and matenanc ex of th Gono Hi wi pl
Pa 4.11.1
Roçky Mountain Power
Idaho General Rate Case. Deçember 2007
Afliate Mgmt Fee (MEHC)
PAGE 4.12
TOTAL
ACCOUNT ~ COMPANY
IDAHO
FACTOR FACTOR % ALLOCATED Bs
Adjustment to Expense:
Management Fee 930 (1,693,460)SO 5.755%(97,467)
Adustment Detail:
MEHC Management Fee limit per commitment 9
MEHC Management Fee Biled - CY 2007
Adustment Required
7,30,000
8,993,460
(1,693,460)
Desçrlptlon of Adjustment:
In merger Commitment # 128, the Company committed to hold customers harmless for costs that were previously assigned to affliates
relating to management fees and set the total company amount at $1,500,000. This commitment is offettable to the extent PacifiCorp
demonstrates to the Commission's satisfaction that corprate allocations from MEHC to PacifiCorp included in PacifiCorp's rates are less
than $7.3 millon. This adjustment limits Corporate allocations from MEHC included in rates to th $7.3 millon limit.
Rocky Mountain Power
Idaho Genal Rate Case. Decembe 2007
Postage Expense
PAGE 4.13
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED ~
Adjustment to Expense:
Customer Receipts & Collecions 903 2 152,823 CN 4.064%6,210 4.13.1
Customer Recipts & Collectons 903 3 152,823 CN 4.064%6,210 4.13.1
305,646 12,421
Descption of Adjustment:
This adjustment refec postage rate incrases on May 14, 2007 and May 12, 2008 for cutomer billngs.
Rocky Mountain Power
Idaho General Rate Case December 2007
Postage
Postal Service Increase for Utilty Bil Mailngs. May 14, 2007 Increase
Current Rate
New Rate
Increase
Total Customers (per JAM factor calculation for CN)
Increase in Customer Postage Costs (January 1, 2007 through May 14, 2007)
Calculated at 1 bill pe customer em $0.02 for 4.5 months
Postal Service Increase for Utilty Bil Mailngs. May 12, 2008 Increase
Current Rate
New Rate
Increase
Total Customers (per JAM factor calculation for CN)
Increase In Customer Postage Costs (12 Months Ending December 2008)
Calclated at 1 bil per customer em $0.012 for 7.5 months
Page 4.13.1
0.29
0.31
0.02
1,698,035
152,823
0.312
0.324
0.012
1,698,035
152,823
Rocky Mountain Power
Idaho General Rate Case. December 2007
Insurance Expense
PAGE 4.14
TOTAL
ACCOUNT ~ COMPANY
IDAHO
FACTOR FACTOR % ALLOCATED B.
Adjustment to Expense:
Injuries and Damages 925 3 (2.556,032)SO 5.755%(147,112) 4.14.1
Description of Adjustment:
This adjustment normalizes injury and damage expenses to reflect a three year average of gross expense minus insurance receivables.
This adjustment also examines the level of captive insurance expense in the test period to $7.4 millon as agreed to by the company as
part of the MEHC transaction as stated in Idaho Docket PAC-E-05-8, commitment 129. This adjustment also examines Propert
insuranc expense to ensure a normalized level.
Rocky Mountain Power
Idaho General Rate Case - December 2007
Insurance Expense
Page 4.14.1
Jan - Dec 2005 Jan - Dec 2006 Jan - Dec 2007
Accruals Accruals Accruals
Totals
Accruals
Excluding Auto (280311)(703,290)(2,107,44)(8,990,118)
(251,373)(293,998)(1,084,570)
(50,000)(25,000)(50,000)
(1,004,663)(2,426,446)(10,124,688)
284,948 0 4,717,560
(719,715)(2,426,446)(5,407,128)
Auto (280312)
Construction (280313)
Receivable *
Net - Accrul Minus Receivable
3 Year Average
(11,800,856)
(1,629,941)
(125,000)
(13,555,797)
5,002,508
(8,553,289)
(2,851,096)
* A reeivable is established at the time the reserve analysis (accral) for a given incident goes above the
insurance deductible. These monies are not received until after the incident is setted, paid. At that time a
claim is submitted to insurance company.
Adjustment Detail:
Base Year Exnse
Minus Insurce Recivable
Net Ba Year Expense - Cot Center 13272
Thre year Avere
Regulator AdjUtment
$10,124,68 Abe
(4,717,56) Abve
5,407,128 Abve$
$2,851,096 Above
$(2,556.032) Pg 4.14
Page 4.14.2
Rocky Mountain Power
Idaho General Rate Case. December 2007
Insurance Expense
Capti Captive
Liabilty Propert Propert
Insurance Insuranc Exnse
Adjustment Detail:548523/925 5422/925 548000/924 Total
Base Year Exnse 1.599.311 5.607,910 10,314.192 17.521,413
Maximum Normalied Levels 1.60.00 5,800.000 10,440,000 17.84.00
Regulatory Adustment
Pg 4.14 Pg 4.14 Pg 4.14
Rocky Mountain Power
Idaho General Rate Case. December 2007
Compliance Departent
PAGE 4.15
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Ofce Supplies & Expenses 921 3 362,000 SO 5.755%20,835
Operaion Supervision & Engineering 560 3 2,449,130 SG 6.048%148,122
Maint SUpervisio & Engineering 590 3 97,870 SNPD 4.682%4,583
Maint of Statin Equipment 592 3 237,600 SNPD 4.682%11,126
Loa Dispatching 561 3 134,64 SG 6.048%8,143
Loa Dispatching 581 3 493,480 SNPD 4.682%23,107
Opration SUpervision & Engineering 580 3 126,390 SNPD 4.682%5,918
3,901,110 221,833 4.15.1
Description of Adjustment:
On June 18, 2007 the FERC approved enhanced compliance requirements imposed by the North Amerin Elecric Reliabilty
Corpration (NERC). Utilities and other bulk power industry participants that violate any of the new standards will face enforcement
actions incuding possible sanctions of up to $1.0 milion per day, in addition to potentially more rigorous compliance monitoring and
testing requirements. In order to comply with the enhance reliabilty standards, the Company plans to add 13 full-time emplyees
and incase proram and information technology costs.
Rocky Mountain Power
Idaho General Rate Case. December 2007
Compliance Expenses
Department
General Counsel
Main Grid Planning
Transmission Development Planning
Investment Planning
Physical Security
Transmission & Distnbution Operations
Transmission & Distribution Operations
Transmission & Distribution Operations
Transmission & Distribution Operations
Finance
Finance
Finance
Finance
Total
Account
921
560
560
590
921
592
561
581
580
921
560
580
581
Page 4.15.1
12 Months
Ending
12131/2008
269,525
718,780
1.701,370
97,870
84,00
237.600
134,64
117.48
55.440
8,475
28.98
70.950
376.000
3,901,110
Rocky Mountain Power
Idaho General Rate Case. December 2007
A&G Cost Commitment (MEHC)
PAGE 4.16
Adjustment to Expense:
Administrive & General
TOTAL
ACCOUNT ~ COMPANY
IDAHO
FACTOR FACTOR % ALLOCATED Bl
930 3 (225,623)10 Situ (225,623) 4.16.2
Description of Adjustment:
The curnt normalized A&G expense is below the MEHC Merger Commitment as stipulated in the Idaho merger comittment 131.
Therefore, no adjustment is necessary. However, ths adjustment also reflecs Idaho's share of the $500,000 per month
administrtie and general expense deferred savings due to the MEHC merger. The savings will be amorzed over 3 years starting
January 1, 208.
4.16.1
Rocky Mountain Power
Idaho Generl Rate Case - December 2007
A&G Expense Cost Commitmt
Description Acunt(s)Tota Company Code Allocation %idaho Ref.#
Deembe 207 Acual Adinistrative and General Expens 180.35,471 Vanous Various 9.526.567 2.2
A&G Adjustmets:
Miscellaneous Genera Expese 921.923,930 (70.515)SO 5.755%(4.058)4.1
Miscellanous Generl Expese 921 (202)WY-Aß 0.00%4.1
Miscellans General Expese 930 (1.210)UT 0.00%4.1
Remove NoRecuning Exse 921.922.931 981,934 SO 5.755%56.515 4.2
Remve NoRening Expese 928 (2.353.55)SG 6.04%(142.341)4.2
Blue Sky 921,922,923 (175.06)SO 5.755%(10.095)4.4
Blue Sky 921 (1.26)10 100.00 (1.264)4.4
Blue Sky 921.923 (55.84)Situs: Non-Idah 0.00%4.4
K2 RIk Mgt Sysem 921.923 (S17.710)SO 5.755%(47.063)4.5
Rent Expens 931 (45.n6)SO 5.755%(26.1n)4.8
Wage and Emplyee Benefits - Annualiion 922. 929. 935 285.019 SO 5.755%16,40 4.9
Wag an Empe Benefits - Annualization 920.935 1,125 10 100.00%4.9
Wag and Emplyee Benefis. Pr Forma 922.929,935 959.017 SO 5.755%55.196 4.9
Wage an Empyee Benefits - Pro Forma 920,935 3.78 10 100.00%4.9
MEHC Transitn Savings-Typ 1 920 (3.353.90)SO 5.755%(193.034)4.10
MEHC Transti Savings-Typ 1 930 610.246 10 100.00%610.246 4.10
MEHC Transin SavingsTyp 3 920 (1,151.305)SO 5.755%(66.263)4.10
Afliate Magement Fee 930 (1.693.46)SO 5.755%(97.467)4.12
Inur Expense 925 (2.556.032)SO 5.755%(147.112)4.14
Coplan Expese 921 362.00 SO 5.755%20.835 4.15
A&G Cost Coitment 930 (225.23)10 100.00 (225,623)4.16
Membehip & Subsipions 930 314.039 SO 5.755%18,075 4.18
Idah Internor Funing 930 28.865 10 100.00%28.865 4.19
Idho Pesin Expese Cash Basis 930 17.929.581 SO 5.755%1.031.936 4.20
West Valy Le and Cotr Termnati 930 (241.50)10 100.00 (241.500)5.3
Total A&G adJstmnts 8.323.355 636.078
Adjusted A&G Expese 188,679.826 10,162,646 2.2
Reqired Adjustmnt
Noalize A&G Cost Commitmt Level
Cap Commtmnt pe Doet No. PAC-E..S. Cont No. i 31
Coilnt Esclaio:
Glba inights Facto JEADGOMS - 2007 1.719
Gl Ints Fac JEADGOMS - 20 1.789% In . De 20 val les De 207 va
222.800.00
4.07%
Decbe 200 A&G Cost Commtment 231,872.717
Rocky Mountain Power
Idaho General Rate Case - December 2007
Deferral and Amortization of MEHC A&G Commitment
4.16.2
Amortize over 3 years beginning January 2008
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
225,623
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
Unamorized
Balance Ref#
(676,868)
(658,066)
(639,264)
(620,462)
(601,660)
(582,859)
(564,057)
(545,255)
(526,453)
(507,651)
(488,849)
(470,047)
(451,245)4.16 I
(432,443)
(413,642)
(394,840)
(376,038)
(357,236)
(338.434)
(319,632)
(300,830)
(282,028)
(263,226)
(244,425)
(225,623)
(206,821)
(188,019)
(169,217)
(150,415)
(131,613)
(112,811)
(94,009)
(75,208)
(56,406)
(37,604)
(18,802)
(0)
Rocky Mountain Power
Idaho General Rate Case. Decmber 2007
DSM Amortation Removal
PAGE 4.17
TOTAL
ACCOUNT J: COMPANY
IDAHO
FACTOR FACTOR % ALLOCAED REF#
Adjustment to Expense:
Customer Asistance
Customr Astance
Customer Asistanc
Customer Astanc
908
908
908
908
1
1
1
1
UT
WA
CA
10
Situs
Situs
Situs
Situs (2,04,020) 4.17.1
(2,048.020)
Description of Adjustment:
Idaho allows for recovery of DSM expenses through the system benefit charge (SaC) tanff nder. This adjustment removes Idaho DSM
costs in order to prevent a double recovery through the revenue requirement and scedule 191.
Rocky Mountain Power
Idaho General Rate Case - December 2007
State of Idaho - General Ledger Account 553405
GIL Account Balance Dis play
.. .$~èo,.enfciirre~èyJ.lil.d'()gtúni;;;Ffuité~~JtF~--:au;..._~~~""''~~-''~-'-~--~''~''~-_.':---~::'- ,---~...:~~~
134,983.61
126,772.02
112,310,16
104,125.12
140,423.96
250,034.65
311,361.25
270,631.43
215,813.66
136,560.43
117,181.09
127,822.91
134,983.61
126,772.02
112,310.16
104,125.12
140,423.96
250,034.65
311,361.25
270,631.43
215,813:66
136,560.43
117,181.09
127,822.91
4.17.1
134,983.61
261,755.63
374,065.79
478,190.91
618,614.87
868,649.52
1,180,010.77
1,450,642.20
1,666,455.86
1,803,016.29
1,920,197.38
2,048,020.29 To 4.17
2,048,020.29
2,048,020.29
2,048,020.29
2,048,020.29
2,048,020.292,048,020.29 2,048,020.29
Rocky Mountain Power
Idaho General Rate Case. December 2007
Memberships and Subscriptions
PAGE 4.18
TOTAL
ACCOUNT:D COMPANY
IDAHO
FACTOR FACTOR % ALLOCAED BW
Adjustment to Expense:
Micellaneous General Expenses
Misllaneous Geral Expenss
930
930
1
3
(38.961)
700.000
314,039
SO
SO
5.755%
5.755%
(22.214) 4.18.1
40,288 4.18.1
18.075
Decription of Adjustment:
This adjustment remoes expenses in excess of Commission polic allowances as stated in Idaho Power's Order #29505. National and
reional trae organizations are reconized at 75%. WSCC dues are incuded at 100% since it is a mandated membership. An other
membership dues are removed. This adjustment also includes the incrase in fees over calendar yer 2007 levels in regards to the
mandated membersip in the Westem Elect Coordinating Counil (WECC).
Pag 4.18.1
Rocky Mountain Power
Idaho General Rate Case. December 2007
Membersips and Subscriptions Adjustment Breakdown
Account Description
Remove Total Membehips and Subscptins in Accunt 930.2
93.2 SAP Extct
Amount
(3.866.256)
Natil and Regional Trade Membep Alloncs
930.2 CONSORTIUM FOR ENERGY EFFICIENCY
930.2 EPRI RESEARCH INSTITUTE
930.2 IESNA
930.2 INTERMOUNTAIN ELECTRICAL ASSO
930.2 NATIONL COAL TRANSPORTATION ASSOC
93.2 Natil Electrc Ener Testing Research an Appication Center
930.2 NATIONAL JOINT UTILITIES
930.2 Next Eney Coun
930.2 NORTH AMERICAN ELECTRIC RELIABILITY
930.2 Oxy-Cl Cobuti Advisor Group
93.2 UCA USERSGROUP
93.2 UTILITY WIND INTREST GROUP INC
930.2 ASSOCIATED OREGON INDUSTRIES
93.2 ASSOCIATED TAXPAYERS OF IDAHO INC
93.2 CAIFORNIA CLIMATE ACTION REGISTRY
93.2 IDAHO MINING ASSOIATION
930.2 INTERMOUNTAIN ELECTRICAL ASSOC
93.2 MAUFACTURING 21 COALITION
930.2 NW POWER & COSERVANCY
93.2 OREGON BUSINESS ASSOCIATION
93.2 OREGO BUSINESS COUNCIL
930.2 PACIFIC NORTHWEST UTILTIES COFERENCE COMMITIEE
930.2 PORTLAD BUSINESS ALLIANCE
93.2 ROCKY MOUNTAIN ELECTRICAL LEGUE
930.2 UTAH FOUNDATION
930.2 UTAH MANUFACTURERS ASSOCIATION
93.2 UTAH TAXAYERS ASSOIATION
930.2 WESTERN ENERGY INSTITUTE
930.2 WYOMING TAXAYERS ASSOCIATION
930.2 YAKIMA CONT DEVELOPMENT
930.2 Oth
Tota Meber All:
Ad Bac Or Mebes at 75%
Mebehip Fee ~ 100
93.2 Westem Elecity Cooating Councl
930.2 NORTHERN TIER TRASMISSION GROUP
12.000
1.252.99
500
7.50
1.250
105.00
10.125
25.00
100
25.00
10,00
5.00
54.787
850
20.00
6.00
7.50
5.00
21,00
13.00
19.80
52.302
39.05
18.00
22.50
6.00
20.00
40.00
7.754
5.00
116.655
1.929.677
1.447.258
1,854.300
178.737
Ad Incrse in Memberhip Fee:
93.2 Westem Eleccity Coinating Council 700.000
314.039Tot Adjustment
Note: EEl memberip fee are excluded. As of Febrary 6. 2007 MidAerca Holngs Compay distinued
its membehip with th Ediso Elecc Intitute.
Rocky Mountain Power PAGE 4.19
Idaho General Rate Case. December 2007
Idaho Intervnor Funding
TOTAL IDAHO
ACCOUNT .!COMPANY FACTOR FACTOR % ALLOCATED BS
Adjustment to Expense:
Misc. General Expenses 930 3 28,865 10 Situ 28,865 4.19.1
Adjustment to Rate Base:
Deferrd Regulator Expenses 182M (28.865)10 Situs (28.86) 4.19.1
Description of Adjustment:
This adjustment amortzes the Idaho intervenor funding regulatory asset over a perid of one (1) year.
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Rocky Mountain Power PAGE 4.20
Idaho General Rate Case. Deber 2007
Idaho Pension Expense Cash Basis
TOTAL IDAHO
ACCOUNT ni COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:Pension Exe 930 17.929.581 SO 5.755%1.031.936 4.20.1
Description of Adjustment:
This adjustment replaces th actuarially determined pension expense for 12 months ended December 2007 with the actual amount funed
(cash basis).
Rocky Mountain Power
Idaho General Rate Case. December 2007
Conver Actuarial Pension Expense to Cash Basis
Cash Basis Pension Expense
Pension Funding CY 2008
Electric Porton
65,627,000
95.402%
62,609,218
96.225%Non-Joint Venture Portion
Pension Funding to Electrc Expense
Accrual Basis Pension Expense
Account 501100 Pension/Superannuation 12 mos ended 1213112007
Pro Forma Adjustment to 1212008 Budget in WEBA Adjustment
Actuarial Pension Expense in Results
47,272,772
(11,958,208)
Total Difference
O&M portion
Adjustment to O&M
Pa 4.20.1
60,245,701
35.314,56 Ref4.9.7
24,931,137
71.92%
17,929,581 Ref 4.20
5
ID RE PROl Pa 5.0 T_
Net ~ Co Adii (Tal 5)
TOTAL
5.1 5.2 5.3 5.4 5.5 5.6 0
Wes Valy Le JamRier
(ME)&Cll Ro oi I E1 Lae
Tot Noli NPT3St Gr Taii Ter LiMl se SPA Ei 0
1 () Reen2 Ge Bu Reenue
3 Intert4 Sp sa 64.3,311 64.35,311
5 Ot Opll Reen 44.167 44.167
6 Tol () Re 64,602,478 64.35.311 44.167
7
6 Op ex9 SIe Pn 2.00.89 2.00.8910 Nu Pr11 Hy Pr12 Ot ~ Sup 88.988.978 64.763,2 (SS.961)(98.43)(157.94)5.368.2313 Tra 746.239 746,23914~15 eu Acti16 eu Se & In17 sa18 Ai & Ge (241.50)(241.50)
19 Tot O&M Ei 91.50.416 87,516,2 (SS.961)(1.169.932)(157.94)5.3.02320 De (55)(55)21 Am (10,5)(10,5118)
22 T_ Ot ll In23 In Tax Fe (2.2.123)(1.05.76)18.697 39.611 149._52.772 (1.79.510)
24 Slte (30.56)(143.46)2.541 53.621 20,256 7.171 (24370)
25 De In T_26 Ines Tax cil Ad27 Ms ~ue & Ex
26 Totl Op Ex 88.951.563 86.317.011 (34.723)(732.649)169.325 (98,05)3,330,805
29
30 Opti Re Fo Re:(4,149.08)(1,96,700)34,723 73.6411 276.642 98,00 (3.33.60)
31
32 RatiBa:33 E1 Pl In Se (242.185)(85,27)(178.26)
34 Pl He fo Fu Us35 Ms De De 142.34 142.349
38 El Pl Ac Ad37 Nu Fu38 Prym
39 Fue St 90,21 90,21
40 Me & Su
41 Worln C842 Wøa i.
43 Ms Ra Ba
44 Tot EI PI (9,58)(65,27)55.673
4S
46 De47 Ac Pr Fo De 2.611 2.111
48 Ac Pr Fo Am 38.3 38.3
49 Ac De in Ta5O~1T51 Cu MY Fo Co52 Cu Se De53 Mi De (187,5$)(187.65)
54
SS Tot Deii (146.68)40,971 (187.8SS)
56
57 Tot Ra Ba (156.2)(24,2)(131.982)
56
5960 Es RO im .1.64 -0777%0.014%0.2%0.110%0-04 -1.319%O.l
61
62
63.. TAXCACUlTI
8586 Op Reen (6.88.788)(3.159.92)SS.981 1.181.081 44.167 157,98 (5,368,23)
67 Ol De
68 In (NUDe)
69 In70 SC'M" Adll71 SC"M" De ,-
72 In II Tax (8.86.788)(3.159.92)SS.961 1.181.081 44.167 157.94 (5.388,23)
7374 Sl In T_(303.56)(143.46)2.541 53,621 20,256 7.171 (243.70)
75
76 Tua In (6.383.208)(3.016.462)53,421 1,127,460 425.911 150,777 (5.124,315)
7778 Feal In T_(2.2,123)(l,OSS.762)18,697 394.611 149.069 52,772 (1,79510)
Rocky Mountain Power PAGE 5.1
Idaho General Rate Case - December 2007
NPCT3Study
TOTAL IDAHO
ACCOUN1!m COMPANY FACTOR FACTOR % ALLOCATED B.
Adjustment to Revenue:
Sales for Resale
Exiting Firm PPL 447NPC 3 676,58 SG 6.048%40,919
Exsting Firm UPL 447NPC 3 (421,557)SG 6.048%(25,496)
Post-mergr Firm 447NPC 3 1,379,704,999 SG 6.048%83,443,700
Nonfi 447NPC 3 13,621,686 SE 6.58%897,187
Tras. - Of system sales 447NPC 3 SG 6.04%
Totl Revenue Adjustments 1,393,581,712 84,356,311 5.1.1
Adjustment to Expense:
Puch Power
Exiti Fir Deand PPL 555NPC 3 (55,175,433)SG 6.048%(3,336,976)
Existing Firm Demand UPL 555NPC 3 37,430,548 SG 6.048%2,26.776
Existing Firm Enery 555NPC 3 (21,334,079)SE 6.586%(1,405,161 )
Post-mergr Fir 55NPC 3 1,214,958,098 SG 6.048%73,479,910
Seary Purchases (Non-Firm)555NPC 3 (45,241,618)SE 6.586%(2.979,823)
Seaal Contracts 55PC 3 10,46,190 SSGC 6.480%678,227
Othe Generation 555NPC 3 3,152,881 SG 6.048%190,684
Post-Merger Firm Typ 1 555NPC 1 SG 6.04%
Total Purcased Powr Adjustment 1,144,256,586 68.890,638 5.1.1
Whe
Existng Firm PPL 565NPC 3 (5.768.382)SG 6.048%(34,868)
Exiting Firm UPL 565NPC 3 11,150 SG 6.04%674
Post-mer Firm 565NPC 3 19,915,289 SG 6.048%1,20,464
Nonfirm 565NPC 3 ( 1,670.577)SE 6.586%(110,032)
Tota Wheein Exse Adj 12,487,48 746,239 5.1.1
Fuel Conume 501NPC 3 26.714,019 SE 6.586%1,759,509
Oter Stea 503NPC 3 (1,293,419)SE 6.586%(85,191)
Natural Gas Expse 547NPC 3 255,108,156 SE 6.58%16,802,605
Peaker Fuel Exns 547NPC 3 (34,486,953)SSECT 7.490%(2,583,107)
ChollaAPS Fue Expese 501NPC 3 5,458.608 SSECH 6.089%332.381
Tot Fue Exp 251,5õ,410 16.226.198 5.1.1
1,506,163Net Por Co 14,66,763
Remove Wyoming PCAM Deferrs 555NPC 1 27,33,271 SG 6.048%1,653,160 5.1.
Description of Adjustment:
Th net po cot adustment noralizes por costs by adjusting sales for resale, puchse poer. whling and fu in a manner
I
consistent with th cotrct tenns of sales and purcse agreements, and nonnal hydro and weather coitions for the twve-
month peri ening Decmber 31, 2008. The GRID study for ths adjustment is based on 2007 act los.
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Rocky Mountain Power
Idaho General Rate Case. December 2007
Net Power Cost Adjustment
Amounts removed from accunts to make the consistent with GRID
Non-Net Power Costs
Sales for Resale (Account 447)
Transmission Services - revenues received not included in GRID
On System Whoesale sales - these are not included in GRID
Purchased Power (Account 555)
BPA regional adjustments - these are crits that are passed
to customers in the northwest and are not included in GRID
Fuel Expense (Accounts 501.503 and 547)
Cholla:
Cholla fuel handling
Cholla start-up diesel
Othr non GRID Cholla
Other Plants:
Fuel handling
Start up gas
Diesel
Residual disposal
Other non GRID
Total non-NPC costs to remove to match GRID
Other adjustment to make accounts consistent with GRID
Adjustment 5.2 - Green Tags
Page 5.1.2
834,438
6,781,850
7,616,288
(22,499,508)
1,592,138
169,657
1,205
1,762,999
5,007,693
572,774
6,511,285
701,993
26,236
12,819,982
(15,532,814)
(849,64)
Page 5.1.3
Rocky Mountain Power
Idaho General Rate Case. December 2007
Net Power Cost Adjustment
Seasonal Contracts
Morgan Stanley p244840
Morgan Stanley p244841
UBS p268848
5,282,160
1,744,080
3,439,950
10,466,190
Rocky Mountain Power PAGE 5.2
Idaho General Rate Case. December 2007
Green Tag
TOTAL IDAHO
ACCOUNT :I COMPANY FACTOR FACTOR % ALLOCATED BE
Adjustment to Revenue:
Green Tag Purchases 555NPC 1 (849.640)SE 6.586%(55.961)5.2.1
Description of Adjustment:
Revenues an expnses of the Blue Sky prms nee to be excluded from results. Thi adjustment remves gr ta pusecots for th pr.
Rocky Mountain Power
Idaho General Rate Case December 2007
Green Tag Adjustment
Page 5.2.1
January - December 2007
Account
546536
1,014,376
Account
546538
(164,736)
Total
849,640
Ref 5.2
These accounts record green ta purchases which must be removed from results because
they are purchased for the Blue Sky program.
Rocky Mountain Power PAGE 5.3
Idaho General Rate Case. December 2007
West Valley Lease (MEHC) & Contract Term
TOTAL IDAHO
ACCOUNT Im COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Generaüon Expnse 54 3 (8.018,163)SSGCT 6.150%(493,149)
Rents (Other Genration)550 3 (6.224,389)SSGCT 6.150%(382.825)
Maintenance of Strures 552 3 (92,630)SSGCT 6.150%(5,697)
Maintenanc of Gen & Electric Plnt 553 3 (577,662)SSGCT 6.150%(35,529)
Maint Mise Oter Power Gen 554 3 (136,632)SSGCT 6.150%(8.403)
Other Expense 557 3 r.OO)SSGCT 6.150%~2,83~
(15,5,485)(9~8,432:5.3.1
Dereation Expe 4030P 3 (8,971)SSGCT 6.150%(552)5.3.1
Amtio Expense 4040P 3 (172,306)SSGCT 6.150%(10.598)5.3.1
lea Redn Amortizaüon 93 3 (241,500)ID Situs (241,50)5.3.2
Adjustment to Rate Base:
Prime Mover, Leahold Improvements 343 3 (1.061,022)SSGCT 6.150%(65,257)5.3.1
Acm Deprecaüon Reserve 1080P 3 42,461 SSGCT 6.150%2,611 5.3.1
Acm Amortzatin Reserve 1111P'3 623,695 SSGCT 6.150%38,36 5.3.1
Description of Adjustment:
The Copany terinated the West Valley lease on May 31. 2008. This adjutment removes seven months of expnse and rate
base from reslts. Thi adjustment also incudes amortzation of the defer lease expense reduction for January 2008 -
Deber 2008.
Page 5.3.1
Rocky Mountain Power
Idaho General Rate Case. December 2007
West Valley Lease
Since the lease expired May 31, 2008, remove June 2007 - Decembe 2007 from results
to reflect the future expense. This wil include the termination payment paid in June 2007.
Remove Leave In
Operation & Maintenance Account Total 2007 June. Dec Jan. May
Generation Expense 548 8,999,447 (8,018,163)981,284
Rents (Other Generation)550 10,977,691 (6,224,389)4,753,302
Maintenance of Structures 552 92,698 (92,630)68
Maint of Gen & Elect Plant 553 624,790 (577,662)47,128
Maint of Mise Other Power Gen PI;554 136,817 (136,632)185
Other Expenses 557 82,718 (46,009)36,710
Total June - Dec O&M Expense 20,914,161 (15,095,485)5,818,676
Depreciation & Amortization
Depreciation Expense 4030P 14,531 (8,971)5,560
Amorization Expense 4040P 293,921 (172,306)121,615
Rate Base
EPIS 343 1,061,022 (1,061,022)
Accm Depreciation Reserve 1080P (42,461)42,461
Accm Amorization Reserve 1110P (623,695)623,695
Rocky Mountain Pow
Idaho General Rate Case Settlement
West Valle Lease Reductn Page 5.3.2
CY 2008 Amoriztion (241,500) 930 sius - no ECD
DEFERRAL
Benning InteretCl Ending
Balance Deferrl Ida Porton*8.8278%Balance
3/3112 125.100 9,463 9.463
4l300 9.463 417.000 31.542 70 41,074
5/3112 41,074 417,00 31,542 302 72.919
6130006 72,919 417,00 31,542 536 104.997
71311206 104.997 417,000 31.542 772 137.312
8111200 137,312 417.000 31.542 1.010 169,864
9130006 169.864 417.00 31.542 1.50 202,656
101311200 202,656 417.00 31.542 1.491 235.689
11l300 235,89 417.00 31,542 1,734 268,965
12111200 268.965 417.000 31.542 1.979 302.486
113112007 302.486 417.000 31.542 2.225 336.253
21812007 336.253 417,000 31,542 2.474 370,269
31112007 370.269 417.00 31.542 2.724 40.535
4130007 404,535 417.00 31.542 2.976 439.053
5/112007 439,053 417,00 31.542 3.230 473,825
6130007 473,825 417.00 31.542 3.48 508.853
713112007 508,853 417,00 31,542 3,743 54.139
81112007 54.139 417,00 31,542 4.00 579.684
913012007 579.68 417.00 31,542 4.26 615.491
101112007 615,491 417,000 31.542 4.528 651,561
1113012007 651.561 417.00 31,542 4,793 687,896
121112007 687.896 417.000 31,542 5,061 724,499
*Pe th transaction agremet. costs ar aHte to Idah based on SSGCT at 3111200
113112008
2191008
31112008
413012008
513112008
61012008
713112008
81112891308
101311200811l3008
121112008
11311200
2181009
31112009
41301200
5/11200
61301200
71311200
81112009
9101009
101112009
1113012009
121112009
113112010
2181010
31112010
41312010
5/1120106/10
713112010
813112010
9l32010
101112010
1113012010
1213112010
Beinning
Balance
724.499
704,374
68,249
664,124
643.999
623.874
603.749
583,624
563,499
543,374
523,249
503.124
482.999
462.874
442.749
422.624
402.499
38.374
362,249
342.124
321.999
301.874
281.750
261.625
241.50
221.375
201,250
181.125
161.000
140,875
120,750
100.625
80,50
60,375
40.250
20.125
AMORTIZAnON
Idaho
Amortion
(20.125)
(20.125)
(20,125)
(20.125)
(20.125)
(20.125)
(20,125)
(20.125)
(20.125)
(20,125)
(20.125)
(20,125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20,125)
(20.125)
(20,125)
(20.125)
(20.125)
(20.125)
(20.125)
(20,125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
(20.125)
Ending
Balance
704,374
68.249
66.124
643,999
623,874
603.749
583.624
563.499
543.374
523.249
503.124
482,999
462.874
442,749
422.624
402.499
382.374
362.249
342.124
321.99
301.874
281,750
261.625
241.500
221.375
201.250
181.125
161,00
140,875
120.750
100.625
80.50
60.375
40.250
20,125
o
Rocky Mountain Power
Idaho General Rate Case. December 2007
James River Royalty Ofet 1 Uttle Mtn
PAGE 5.4
TOTAL IDAHO
ACCOUN1~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Oter Electc Revenue 456 3 6,565.987 SG 6.048%397,107 Bel
Other Electc Revenue 456 3 811,188 SG 6.048%49.060 Bel
7,377,175 446,167
Adiustment Detail:
12 Months Ended
1213112008
6.085,678
480,309
6.565,987
5.4.1
5.4.1
James River Ofet
Capital Recvery $
Major Maitenance AHowance
Total Ofset
Ljte Mountain Revenue Forecast
Expcted Steam sales -12 months ended 12131/2008
Less: Stea sales in unadjusted results
5,133,517
4,322,329
811,188
Description of Adjustment:
This adjustment credits revenues for capital cost and maintenance cost recvery of the James River facility. This adjustment also
Inceases Uttle Moutain steam sales to the level expected in the test peod.
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Rocky Mountain Power PAGE 5-.5
Idaho General Rate Case. Decmber 2007
Electic Lake Settlement
TOTAL IDAH
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED BW
Settlement of Costs:
Settlement Reimbuement Fixed 311 1 (2,925.421 )SG 6.048%(176.928)5.5.1
Amortatio Reimbursement O&M 557 1 (2.661,594)SG 6.048%(160,972)5.5.1
Unamorted Reimbursement O&M 25399 1 (1,431.680)SG 6.048%(86.587)5.5.1
Regulatory Ast 186M 3 2,161.242 SE 6.586%142.349 5.5.1
Regulator Liality 254 3 (1,534,482)SE 6.58%(101,06)5.5.1
Fuel Stock 151 3 1,370.249 SE 6.586%90.251 5.5.1
New Pumping Arrangement:
O&M 557 1 50.00 SG 6.048%3,024 5.5.1
Description of Adjustment:
This adjustment recnizes a 2008 settlement agreement which reimburss the Company for legal expenses, other O&M and
capital costs assoiated wi pumping water back into Elecc Lake.
Rocky Mouin Po_
Idho General Rat Cas Decbe 2007
Ele Lae seement
Settemen of CostsValu of 8etUCapil PoiRed to C8 Ac 311
Val of Se
OftO&MRe of O&
Am Ac 25Amoti Ac 25
Regat Lia Ac 253
Of O& Ac 557Am of OfRe Liit Bala
Regto Ast 186.5
Set.t Deer AsseAmonEn Bala
De 07 . De 08 Beg I Enng Avere
Reato Li Ac 254
SeUp De AsseAmotiEnd Ba
De 07 . De 08 Be I En Ave
Fue Sto 151.1Bala De 207Bal De 200
En Baanc
De 07 . De 08 Beg I Endin Ave
N_ Pumng Agrent
Annu Paymnt to CFC
RMP Curr CoNe ag ine
10.087.658
29%
2,925,421 Ref 5.5
10.087.65
71%
7.162.237
(715.84)
(1.945.754)
(2661,59)Ref 5.5
200
2.147.520
(715.84)
1,41,680 RefS.5
207 20
7.062,98
(2,740.49)
4.322.48
2,161,22 Ref5.S
207 20
(5,014.717)1.94.754
(3,06,96)
(1,5,482)Ref 5.
D.Joto Cl Totl
1.067.99 1,67,50 2,740,49
1.067,99 1,612,50 2.740.49
53.99 83.250 1,370,249 Ref 5.
240.00
190,00
50,000 RefS.S
Page 5.5.1
Rocky Mountain Power PAGE 5.6
Idaho General Rate Case - December 2007
BPA Exchange
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR %ALLOCATED B!
Adjustment to Expense:
Purchased Power Expense 555 1 12.992,463 OR Situs
Purchase Power Expense 555 1 4.139,022 WA Situs
Purchased Power Expense 555 1 5,368.023 10 Situs 5,368,023
22,499,508 5,368,023 5.6.1
Description of Adjustment:
The Company received a monthly BPA purchase power credit from BPA. This credit was treated as a 100% pass-through to
eligible customers. Both a revenue credit and a purchase power expense credit were posted to unadjusted results. Both of
these transactions are to be removed from results. This adjustment reverses the BPA purchase poer expense credit
recorded. The BPA revenue credit is removed from results in revenue adjustment 3.2. BPA discntinued the credit in May
2007. The pass-through of the credits was discontinued in Idaho Docket No. PAC-E-07-10, Order No. 30329.
Rocky Mountain Power
Idaho General Rate Case Deember 2007
SPA Regional Exchange Creit Reversl
Pag 5.6.1
Primary Account Account Name Alloc Total Oreaon Wash Idaho
551100 REG BILL OR-(PACF)OR (12,992,463 (12,992,463)
551200 REG BILl-WA (PACFl WA (4,139,022 (4,139,022)
5551330 REG BILL-IO (UTAHl 10 (5,368,023 (5368023)
(Business Warehouse Data)$ (22,499,508)
6
ID REED PRTOCOL Pa 6.0 Tot
De & Am (Tab 6)
TOTAl
6.1 6.2 6.3 6.4 0 0 0
Deti &De &Amli Am Hy Ne DeliTot No Ex Reei Deioning Ra 0 0 0
1 Op Re_2 Ge Bu Re3 Inrll
4 Spe sale5 Ot Opat Re
6 Tot Op Re
7
8 Op Expi:g si Pr10 Nu Pr
11 Hyro Pruc
12 Ot Po Supp 13 Trans14 DI15 eusAc16 Cuto 5e & In
17 Sa18 Ad & Ge
19 Tot 0&.. Ex20 Deli (927,58)2,577.474 216,2 (3.721.258)
21 Amli 76.826 76.826
22 T_OtThan In23 In Taxii Fed 284,246 (88.828)(72.23)1.43.310
24 Slate 38.824 (120.50)(9.815)168.45
25 De In T_
26 Invetm Tax Cr. Ad.27 Ms Re & Exen
28 Tot Opg Exse:(527,886)1.64.967 134.150 (2.309.004)
29
30 Op Re Fo Re:527,886 (1.64.967)(134.150)2.309.004
31
32 Ra Ba
33 EIe Pl in SIl34 PI He fo Fut Us35 Ms De De
36 EI Pl Ac Ad37 Nu Fu38 Prym
39 Fu Sl
40 Mate & Supp41 Wll Çal42 Weattli Lo
43 Ms Ra Ba
44 Tol El Plnt
45
46 De:47 Ai Pi Fo De (1.630.642)(1.630.842)
48 Ai Pi Fo Am (76.372)(76,372)
48 Ai De In Tax50 Un rre
51 Cu Mv For Co52 Cu Slic Depo53 Mi De
54
55 Tot De:(1,707.14)(1.707,014)
58
51 Totl Ra Ba (1.707.014)(1.707.14)
58
5960 Estite RO im 0.252 -0.65%0.(2%-0.05%0.914%O.ll O.ll 0.00'
61
62
63
84 TAX CACUTI
6586 Oper Re 850.757 (2.65.301 )(216,200)3.721,258
61 Ot De68 InI(AF)
69 in70 SC V Adils71 SC'M" Deuc
72 In Be Tax 85.757 (2.65.31 )(216,200)3.721,258
7374 Slte In T_36.624 (120.505)(9,15)168.94
75
76 Tax In 812.133 (2,533,796)(206.385)3.552,313
n
78 Fe In T_284,246 (686,828)(72,235)1.243,310
Rocky Mountain Power PAGE 6.1
Idaho General Rate Case. December 2007
Depreciation & Amorization Expense
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATEP REF#
Adjustment to Expense:
Steam Production 403SP 2 928,871 SO 6.0479%56,178
Steam Production 403SP 2 43,246 SSOCH 5.7312%2,479
Hydro Producton 403HP 2 61,679 SO-P 6.0479%3,730
Other Producton 4030P 2 12,243,264 SO 6.0479%740,465
Transmission 403TP 2 1,112,150 SO 6.0479%67,262
Distributon. Oregon 4033 2 44,001 OR Situs
Distribution - Utah 403364 2 171,949 UT Situs
Distrbution - Idaho 40336 2 75,873 10 Situs 75,873
Distribution - Wyoming 403364 2 88,941 WYE Situs
General Plant - Oregn 403GP 2 189 OR Situs
General Plant - Utah 403GP 2 2,102 UT Situs
General Plant 403GP 2 13,993 SG 6.0479%846
Intangibl Plant 4041P 2 7,894 SO 5.7555%454
14,794,152 947,287 6.1.
Steam Production 403SP 3 586,805 SG 6.0479%35,490
Steam Producton 403SP 3 2,762,323 SSGCH 5.7312%158,314
Hydro Prouction 403HP 3 34,639 SG-P 6.0479%21,085
Hydro Proucon 403HP 3 266,096 SG-U 6.0479%16,093
Other Proucon 4030P 3 21,123,447 SG 6.0479%1,277,533
Transmissio 403TP 3 1,681,453 SG 6.0479%101,693
Distrbution - Oregon 403364 3 210,272 OR Situs
Distrbution - Utah 403364 3 134,64 UT Situs
Distrbuon - Wyong 403364 3 163,320 WYE Situs
Genel Plant 403GP 3 355,025 SO 5.7555%20,433
Intible Plant 401P 3 1,262,778 SG-P 6.0479%76,372
28,894,802 1,707,014 6.1.1
Description of Adjustment:
This adjustment enters into the test period result depreciation and amortization expense for the major plant added to rate
base in adjustment 8.11.
Pa 6.1.1
Roc Montain Power
Idaho General Rae Case December 2007
Increment Depriaton Expense 2007 Plant Additions Mo Incremel
Plant Depriation Depation Jal17 to De07 Deprciation Expense on
Description Account Account Facor Rae Plant Additions Expense PlanAds.
Stam Proucon Plant:
Varius 312 40P SG 2.35%36.46.544 6 429.03
Varius 312 403SP SSGH 1.511%5,725.924 6 43.246
Bh.eU Botting Cyle 312 403SP SG 2.35%22,165.654 11.5 499.835
Cho.. 4 Envirnmetal 312 403SP SSCH 1.511%6
Blndel U3 Expaion Development 312 403SP SG 2.35%6
U4 Clen Air. NOx 312 40P SG 2.35%6
Totl Steam Plant 64358.121 972,117
Hydr Proion Plant:Varus 332 403P SGP 2.20%5.607.113 6 61.679
Varis 332 403HP SG.U 2.774%6
Vari 332 403H SG 6
Tot Hyro Plant 5,607,113 61,679
Other Produion Plan:
Heriston: U2 CT Roto & Comprssor 343 40 SG 2.634%6
Mar II Wind Expansion (70.2 MW)343 4030 SG 4.04%6
Gono Hills Wind Project (94 MW)34 4030P SG 4.04%6
Glenr Wind Plant (99 MW)343 40P SG 4.048%6
Seve Mile Hill Wind Plant (99 MW)343 4030P SG 4.048%6
Rollng Hils Wind Projec PJ (99 MW)343 40 SG 4.04%6
Glenro III Win Plant 343 40P SG 4.04%6
Sev MI HI II Wind Plant 343 4030P SG 4.04%6
Mang Win Proje (140.4 MW)343 40 SG 4.04%238.339,163 7.5 6,02.59
Lake Side Capl Build 343 4030 SG 2.634%323,067.33 8.5 6,026.820
Var 343 4030P SG 2.63%14.189.084 6 186.845
Tot Other Produon Plant 575.595,581 12,243,264
Transmission Plant:
Various 35 403TP SG 2.06 107.805.899 6 1.112.150
Totl Transmission Plant 107.805,899 1,112,150
Disribution Plant:cali 364 4033 CA 3.79%6
Orn 36 40 OR 2.867%3.069.83 6 44.001
Washing 36 40334 WA 3.125%6
Utah 36 40334 UT 2.513%13.686.089 6 171.949
Idaho 36 40 10 2.569%5,907.426 6 75.873
Wyoin 36 4033 WYP 2.823%6,301.312 6 88.941
Total Disribuio Plant 2896,682 380,764
Genera Plant:Cafoa 397 403GP CA 2.323%6
Orgon 397 403GP OR 2.819%13.401 6 189
Washing 397 40P WA 3.495%6
Ut 397 403GP UT 2.302%182.664 6 2.102
Idah 397 403GP 10 2.421%6
Wyoming 397 40P WYP 3.86%6
Geral 397 403GP SO 7.074%6
General 397 403G SG 3.256%859.476 6 13.992
Totl Genel Plant 1,055,541 16,264
Mining Plant:
Co Min 39 403M se 3.60 6
Total Mining Plant
Intngible Plant:
General 303 4041P SO 8.412%187.683 6 7.89Ge3024041PSG3.93%6
Hyro Relinsing 302 4041P SG.p 2.976%6
Totl Intngible Plant 187,683 7,894
Grand Totl 783,574,601 14,794,152
Ref# 6.1
Rocky Mo Poer Pa 6.1.2
Idaho Genel Rate Cas. Deber 207
Inc~1 Dereiation Expene 208 Plant Additons
IncrentlPlDeprnDepøcatlonJa8 to De Plan ex on Pl
Prct Desripton Ac Fac In-ic Da Acco Rate Additions Adds
Stea Prodn
Ch: CHOLU4 CAl Envir Projes 312 SSCH Ma 40 1.511%170.84.64 2.58.711
CHOUO Co Unin&Handin 312 SSH Jun 40 1.511%6.848.967 103.45
Jim Br U4 Reher Rep 312 SG Ju 403SP 2.35%8.85.93 20.26
Ch lJ 4: TURBINE COMPNT REPL.312 SS Ju 403S 1.511%5.174.067 78.156
Jim Brer U4 Cln Al . NO 312 SG De-0 403 2.35%6.89.58 162.25
Bt U3 Exnsio Deen 312 SG De 40P 2.35%9.191.622 216.283
St Pro Tot 207,8.817 3.34.127
Hy PrduonCo 2 EIe 0v 332 SGP Jan 40 2.20 8.187.687 180.132
INU 4.1.1f So Sps Tai Ba 33 SG-P Ju 403HP 2.20 7.65.248 168.507
Cu 1 Over 332 SG De-0 403H 2.774%9.591.93 268.09
Hyo Pr Totl 25,43872 614,735
Ot PrnLae Sid p__ Oupu Impem & Chlis 34 50 Ap.( I Sø-0 40 2.83%310.551.18 8.178.37
Goo Hil WI Pr (94 MW)343 SG Ju 40P 4.048%188.514.189 7.63.571
Ma II Win Expns (70.2 MW)343 SG Au-0 40 4.04 131.28.96 5.314.03
Ot Prucon Tot 63,34.967 21.123.44
TramisIon
Co il 230115 IN tr. 25 WA 35 50 Ma-0 40TP 2.06%5.871.271 121.139
Cr Flat -In Varia Var Deic 35 SG Ap-0 40TP 2.06%13.917.09 28.144
li 1 COio Pr. Coer Lin 1 to 115 kV 35 50 Se 403TP 2.06%15.716,54 324.279GI wi ge 355 50 Oc-0 40TP 2.06%8.23.63 169,60
Wine Co Su Ne 23115 kV Suatio 355 SG Oc-0 403TP 2.06 6,12.379 134._
Upp Gr Riv Bain pt 35 SG 0C-0 403TP 2.06%12.817.194 28.45
Chpp Cr 23 ci_ Ene Co 20 MW 5e 355 50 De 403TP 2.06%11.411.417 23.44
LoganCany . re 7 mi to 138 kV OCkt 355 50 De-0 403TP 2.06%7.016.62 144.770
Transmision Tot 81.49.574 1,681.45
Dis
El Ho Ins115-12.kV T_ Fdr Su 36 WYP Ma 4033 2.823%5.785.482 183.32
YtN Ave 115-12.5 kV su an ta li 36 OR Ma 4033 2.867%7.33.117 210.272
Comee Su - Ne 138 kV Su 36 UT Ma 40 2.513%5.35.425 134.64
Olbuton Tot 18.479.004 508,2
GeneralCuto IVR Rep a AM Up 397 so Ju 40P 7.074%5.18.628 355.02
Geral Totl 5,018.62 35.025
IntibleU Roue Rel-H So 30 SG.p Ju 404P 2.97 6,13.o3 196.23
Yal Rllnsin Su 30 5O.p Se 401P 2.978%14.28.091 425.018
Me Rel SU 302 SG Se 401P 2.97 11.05.169 328.46
Sw Relin Suic 30 SG-Se 40 2.976%10.48542 311.92
Intible Tot 42.42,815 1,26.778
1,011.019,67 21.89.802
RelU.11.1 Re6.1
Rocky Mountain Power PAGE 6.2
Idaho General Rate Case. December 2007
Depreciation & Amortization Reserve
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Reserve:
Steam Production 108SP 3 (586.805)SG 6.0479%(35,490)
Steam Production 108SP 3 (2,762,323)SSGCH 5.7312%(158,314)
Hydro Production 108HP 3 (348,639)SG-P 6.0479%(21,085)
Hydro Production 108HP 3 (266,096)SG.U 6.0479%(16,093)
Other Prouction 1080P 3 (21,123,447)SG 6.0479%(1,271,533)
Transmission 108TP 3 (1,681,453)SG 6.0479%(101,693)
Distribution - Oregon 108364 3 (210,272)OR Situs
Distribution - Utah 108364 3 (134,644)UT Situs
Distribution - Wyoming 108364 3 (163,320)WYE Situs
General Plant 108GP 3 (355,025)SO 5.7555%(20,433)
Intanible Plant 1111P 3 (1,262,718 )SG-P 6.0479%(76,372)
(28,894.802)(1,707.014)6.2.1
Description of Adjustment:
This adjustment enters into test period results depreciation and amortization reserve for the major plant additions added to
rate base in adjustment 8.11 .
Rocky Mountin Power Pag 6.2.1
Idaho General Rate C_ December 207
Incra Acumulat R_rv 200 Plant Additions Incl
Plant Depriaton Dapatlon JanO to De8 Plnt R_rv on Pl
i,ac Description Ac Fac In-rve Date Acun Rate Addis Ad
Ste Proucton
Ch: CHOlU4 CA Env Pr 312 SSCH May-108P 1.511%170.84.643 2.58,711
CHUO Co Un 312 SSGC Ju 108 1.511%6.84.967 103.45
Jim Br U4 Reh Repl 312 SG J~108 2.353%8.85.93 20,268
Cho Un 4: TURBE CONT REPl 312 SS J~108P 1.511%5,174.067 78,156
Jim Br U4 Cl AW . NO 312 SG De-0 108SP 2.35%6.95.58 162,25
Bl U3 Expa De 312 SG De 108P 2.35%9.191.622 216.283
St Producon Tot 207.80.817 3,34.127
Hyro PrnCo 2 EIe Ovul 332 SG-Jan 108P 2.20 8,187.687 180.132
INU 4.1.1f Soa Spgs Taiaç Ba 332 SG-Ju 108P 2.20%7.659.248 168,07
Cute 1 0v 33 SG De 108HP 2.774%9,591,938 26.09
Hydr Prucion Total 25.4,872 &14.735
Other Prlae Si Pow 0u ~ & Ch 34 SG Ap-0 I Sø-0 108 2.83%310.551.18 8,178.837
Go Hil Win Pr (94 MW)343 SG Jun 1080P 4.04%168.514.189 7.03.571
Mao II Win Ex (70.2 MW)343 SG Au 1080P 4.04 131.283.96 5.314.03
Ot Producon Totl 630,3.967 21.123.44
TrMmlion
Co II 23115 kV irer. 25 WI'35 SG Ma-0 108TP 2.06 5.871.271 121.139
Cran Fl . Ins Varia Var De 35 SG Ap-06 108TP 2.06%13.917.09 287.144
li 1 Coerio Pr. Co Lin 1 to 115 kV 355 SG 5e 108TP 2.063%15.716,95 324.279Gl wi gø 35 SG 0C-0 108TP 2.06%8.2.&39 189,8
Wi Co Suti N_ 23115 kV Suio 35 SG oc 108TP 2.06 6.12.379 134._
Up G, Riv Ba pr 35 SG 0C-0 108TP 2.06%12.817.19 28450
Ch Cr 23 ci_ Eney Co 20 MW seic 355 SG De 108TP 2.06 11,411,417 23.44
Loan eø . re 7 mi ki 138 kV DC 355 SG De-0 108TP 2.06 7,016.62 144,770
Tranilulon Totl 81.49.574 1.&81.45
Ditrion
Elk Ho Ins115-12.5k Two Fdr Su 36 WYP Ma 10836 2.82%5,785.48 183.32
V_iw 115-12.5 kV su an ta li 36 OR May-108 2.867%7.33.117 210.272
Cø SUio . Ne 138 kV Su 36 UT Ma 108 2.513%5.358.25 134.64
Dln Tot 18.479.004 508.238
GelCu IVR Rei & MR Up 397 SO Ju 108P 7.074%5,08.&2 35.025
Gene Tot 5.018.&28 35.025
InngbleU Rog Relic SC 30 SG-Ju 1111P 2.97%6.13.013 196.82
Val Re Su 30 SG 5e 1111P 2.976%14.28.091 425.018
Me Rein Su 30 SGP Se 1111P 2.976%11.05.189 328.94
Sw Relin Supe 302 SG-5e H11P 2.976%10,48.542 311.99
Intble Tot 42.427.815 1.282.778
1.011.019.&77 28.894.802
Re8.".'Ref6.2
Rocky Mountain Power PAGE 6.3
Idaho General Rate Case. December 2007
Hydro Decommissioning
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Depreciation Expense 403HP 3 2,224,229 SG-P 6.0479%134,520
Depreciation Expnse 403HP 3 1,350,550 SG-U 6.0479%81,68
3,574,779 216,200 6.3.1
Description of Adjustment:
Based on the Company's latest depreciation study an additional $19.4 millon is required for the decommissioning of various
hydro faciliies. This adjustment includes an annual level of expense in results as approved in the depreciation study.
Rocky Mountain Power
Idaho General Rate Case December 2007
Hydro Decommissioning Reserve
Description
Decommissioning Reserve
Amorzation Perio
Annual Accrual
West Side Resourcs
East Side Resources
West Side Annual Accrual
East Side Annual Accrual
Total Annual Accrual
Pag 6.3.1
Amount
19,410,010
5.43
3,574,779
62.2%
37.8%
2,224,229
1,350,550
3,574,779 To 6.3
Rocky Mountain Power PAGE 6.4
Idaho General Rate Case. December 2007
New Depreciation Rates
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Depreciation Expense 403SP 3 (16,359,113)SG 6.0479%(989,389)
Depreciation Expense 403SP 3 (3,370,978)SSGCH 5.7312%(193,197)
Depreciation Expense 403SP 3 (13,747,134)SG 6.0479%(831,418)
Depreciation Expense 403SP 3 (13,712,328)SG 6.0479%(829,313)
Depreciation Expense 403HP 3 (720,834)SG-P 6.0479%(43,596)
Depreciation Expense 403HP 3 167,874 SG-U 6.0479%10,153
Depreciation Expense 403HP 3 83,585 SG-U 6.0479%5,055
Depreciation Expense 403HP 3 (987,633)SG-P 6.0479%(59,731)
Depreciation Expense 4030P 3 (1,839,081 )SG 6.0479%(111,226)
Depreciaton Expense 4030P 3 (572,511)SSGCT 6.1504%(35,212)
Depreciation Expense 4030P 3 86,672 SG 6.0479%5,242
Depreciation Expense 403TP 3 (1,294,599)SG 6.0479%(78,297)
Depreciation Expense 403TP 3 (728,778)SG 6.0479%(44,076)
Depreciation Expense 403TP 3 (663,275)SG 6.0479%(40,114)
Depreciation Expense 403364 3 1,547,669 CA Situs
Depreciation Expense 403364 3 (313,647)10 Situs (313,647)
Depreciation Expense 403364 3 (43,700)OR Situs
Depreciation Expense 403364 3 (5,343)UT Situs
Depreciation Expense 403364 3 588,475 WA Situs
Depreciation Expense 403364 3 159,929 WYE Sits
Depreciation Expense 403364 3 144,753 WYW Situs
Depreciation Expense 403GP 3 (595)SE 6.5865%(39)
Deprecation Expense 403GP 3 (371,128)SG 6.0479%(22,446)
Depreciation Expense 403GP 3 (14,955)SSGCH 5.7312%(857)
Depreciation Expense 403GP 3 (515)SSGCT 6.1504%(32)
Depreciation Expense 403GP 3 (881,433)SO 5.7555%(50,731)
Depreciation Expense 403GP 3 (69,522)CN 4.0638%(2,825)
Depreiation Expense 403GP 3 2,059 CA Situs
Depreciation Expense 403GP 3 (89,186)10 Situs (89,186)
Depreciation Expense 403GP 3 (525,353)OR Situs
Dereciation Expense 403GP 3 (278,979)UT Situs
Depreciation Expense 403GP 3 (6,404)WA Situs
Depreciation Expense 403GP 3 95,384 WYE Situs
Depreciation Expense 403GP 3 28,099 WYW Situs
Depreciation Expense 403GP 3 (35,984)SG 6.0479%(2,176)
Depreciation Expense 403GP 3 (69,438)SG 6.0479%(4,200)
(53,797,950)(3,721 ,258)6.4.1
Description of Adjustment:
This adjustment normalizes CY 2007 depreciation expense to reflect the impact of the new depreciation rates which were
effective January 1,2008 in Docket No. PAe-E-07-14.
Rocky Mountain Power
Idaho Genral Rate Case December 2007
New Depreciation Rates
Function
DSTP
DSTP
DSTP
DSTP
DSTP
DSTP
DSTP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
HYDP
HYDP
HYDP
HYDP
OTHP
OTHP
OTHP
STMP
STMP
STMP
STMP
TRNP
TRNP
TRNP
Factor
CA
ID
OR
UT
WA
wyp
WYU
CA
CN
DGP
DGU
ID
OR
SE
SG
SO
SSGCH
. SSGCT
UT
WA
WYP
WYU
DGP
DGU
SG-
SG-U
DGU
SG
SSGCT
DGP
DGU
SG
SSGCH
DGP
DGU
SG
CY20070EPE
5,735,838
6,371,036
43,733,138
49,765,782
10,504,848
10,864,501
2,089.952
247,225
1,384,927
469,209
807,216
866,780
4,387,151
37,603
4,911,245
17,641,227
170,708
16,958
3,989,429
1,384,236
1,716,773
348,623
4,979,312
1,187,400
5,276,568
1,477,963
39,783
29,280,267
3,161,554
37,507,935
40,335,873
60,606,591
9,113,517
12,270,765
13,361,646
31,738,237
417,781,814
Page 6.4.1
2008 Rate Prior Rate Rate % Change OEPE Adjustment Adjusted CEPE3.796% 2.990% 26.982% 1,547,669 7,283,502.569% 2.702% -4.923% (313,647) 6,057.3892.867% 2.870% -0.100% (43,700) 43,689,4382.513% 2.513% -0.011% (5,343) 49,760,4393.125% 2.959% 5.602% 588,475 11,09,3232.823% 2.782% 1.472% 159,929 11,024,433.061% 2.863% 6.926% 144,753 2,234,706
2.323% 2.304% 0.833% 2,059 249,2846.648% 6.999% -5.020% (69,522) 1,315,4053.784% 4.09% -7.669% (35,984) 433,2253.483% 3.811% -8.602% (69,438) 737,7782.421% 2.699% -10.289% (89,186) 777,5942.819% 3.203% -11.975% (525,353) 3,861.7973.464% 3.520% -1.583% (595) 37,003.256% 3.522% -7.557% (371,128) 4,54,1177.074% 7.44% -4.99% (881,433) 16,759,7943.549% 3.889% -8.761% (14,955) 155,7534.281% 4.415% -3.037% (515) 16,4432.302% 2.475% -6.993% (278.979) 3,710,4503.495% 3.511% -0.463% (6,40) 1.377,8323.869% 3.666% 5.55% 95.384 1,812,1512.987% 2.765% 8.060% 28,09 376,7221.727% 2.155% -19.835% (987,63) 3,991.6792.245% 2.097% 7.039% 83.585 1,270.9842.200% 2.548% -13.661% (720,83) 4,555,7342.774% 2.491% 11.358% 167,874 1,645,83710.241% 3.222% 217.863% 86.672 126,4542.63% 2.810% -6.281% (1,839,081) 27,441,1863.320% 4.054% -18.109% (572.511) 2,589,041.957% 3.0890,4 -36.651% (13,747,134) 23,760,8011.987% 3.010% -33.995% (13,712.328) 26,623,5452.353% 3.223% -26.992% (16,359,113) 44,247,4781.511% 2.397% -36.989% (3.370,978) 5,742,5391.929% 2.051% -5.939% (728.778) 11,541,9871.898% 1.997% -4.96% (663,275) 12,698,3702.063% 2.151% -4.079% (1,294,599) 30,443,637
(53,797,950) 363,983,864
Refer Page 6.4
7
IDAHO REVSEi) PRTO Pag 7.0TOI
Tax AdbnlS (Tab 7)
TOTAL
7.1 7.2 7.3 7.4 7.5 7.6 1.7
Pag 1 . De Page 2 . De
Pr Tax Re Engy De Incme IncTax Inc Tax
Tot Norli In Tru Up Ex Tax Cre ScM Tax Ex Ba Bal
1 Op Reen:2 G__ Buins Reven
3 lnttal4 Spe Sal
5 Ot Op Revenues
6 TOI Op Reen
7
8 Opng Expees:9 St Pr10 Nuc Pr11 Hy Pr
12 Ot "- Su13 Trasio14 D1tr15 eu Ac16 C~ Seic & Inf17 Sa18 Ade & G_aI
19 Tot o& Expees20 De21 Am
22 Taxes Ot Thn In 607,971 607.971
23 In Taxes: Fed (4.99.367)(1.120.89)(20.129)(1.76.43)(1.901.90)
24 S_(475,925)(152.310)(27.60)(37.575)(258,43)
25 Deed Inc Taxes 2.56.264 2,56
26 Investm Tax Cre Adj.48.647 48.647
27 MIe Reven & Expese
28 Tot Opng Expenses:(1.80,411)(1,273201 )3n.240 (1,802,014)(2.160.347)3.051,910
29
30 Ope Rev For ReI:1.80,411 1.7301 (377,240)1,80.014 2.160.347 (3,051,910)
31
32 Ret Bae:
33 ei Plt In Seic
34 PI He fa Futre Use35 MIe De De
36 EI PI Ac Ad37 Nu Fue38 Pr
39 Fue Sto40 Ma & Supp41 Wor Capl42 Wed Loa
43 MI Rat Bae
44 Tot EI Pl
45
46 De:47 Acc Pr For De46 Ac Pr For Am
49 Ac De Inc Tax (68.611)(1.75.901)1.074,2
50 Ui IT (62.84)(11,8)
51 Cus_ Aå For Cont52 Cus_ Seic Depoit53 Mlce De
54
65 Tol De:(743,456)(1.754.901)1,011,44
5&
57 Tol Ra Ba:(743.456)(1.754.901)1.011,44
58
5980 Esll ROE Im 0.73%0.50%-0.149%0.714%0.85 .1.20 0.04 -0.02
61
11
63
64 TAX CACULTIO
6568 0p Reven (607,971)(60.971)67 Ot Des
68 Int (AFUDC)
69 Int 3.35.85 3,35.8570 Sc'M" Ad (2.263,113)(2,263113)
71 Scul'M" De 3,29,35 3,429.35
72 Inc Bee Tax (9.65289)(3.35.855)(607.971)(5,692.46)
73
74 S_lnc Taxes (475.92)(152,310)(27.60)(37.575)(258.43)
7576 Tax Inc (9,179.36)(3,202.54)(58.370)37.575 (5,434.025)
77
78 Fed Inc Tax . Cal (3,12.777)(1.120.89)(203129)13.151 (1.901.90)
79 Adim to Calculate Tax:
80 Wy Win Tax Credi (1.m.59)(1.777.59)
81 Fed In Taxes (4.99.367)(1.120,890)(20129)(1.764,439)(1.90.90)
Rocky Mountain Power
Idaho General Rate Case. December 2007
Interest True Up
PAGE 7.1
427
427
427
1
2
3
TOTAL
COMPANY
1,516,721
(255)1,838,389
3,354,855
IDAHO
FACTOR FACTOR % ALLOCATED .B
10 Situs 1,516,721 Bel
10 Situs (255)Be
10 Situs 1,838,389 Be
3.354,855 2.18
50,149,389 1.0
3.050%2.1
15,409,077 1.0
13.892,35 2.18
1.516,721 1.0
Adjustment to Expense:
Oter Intert Expense - Type 1
Other Interest Expense - Type 2
Other Interest Expense - Type 3
ACCOUNT Type
Adjustment Detail:
Type 1
Jurisdiction Spific Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Acual Interest Expense
Total Intert True-up Adjustment
Type 2
Jurisdiction Specfic Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Type 1 Interest Expense
Total Interet True-up Adjustment
505,141,026 1.0
3.050%2.1
15,408.822 1.0
15,40(077 1,0
255)1.0
565,40,155 2.2
3.050%2.1
17,247,210 2:18
15,408.822 1.0
1,838,389 1.0
Type 3
Jurisdiction Specc Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Type 2 Interest Expense
Total Interest True-up Adjustmnt
Description of Adjustment:
This adjustment synchronizes interest expense with the jurisdictional allocated rate base by multiplying the rate base by the
Company's weighted cost of debt.
Rocky Mountain Power PAGE 7.2
Idaho General Rate Case. December 2007
Propert Tax Expense
TOTAL IDAHO
ACCOUNT Twe COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustmnt to Expense:
Taxes Other Than Income 408 3 10.563.319 GPS 5.7555%607,971 7.2.1
Description of Adjustment:
This adjustment normalizes the difference between actual acced propert tax expense and expected propert tax expense
resulting from estimated capital additions included in the test period.
Pag 7.2.1
Rocky Mountain Power
Idaho General Rate Case. December 2007
Propert Tax Adjustment
State
Al
CA
CO
10
MT
NM
OR
UT
WA
WY
Other
2007 Net
Property Taxes
1,954,321
1,825,141
1,775,929
2,467,206
2,387,678
11,031
15,861,200
31,081,518
4,146,198
7,30,459
285,746
69,102,427
State
Al
CA
CO
10
MT
NM
OR
UT
WA
WY
Other
200 Estimated
Net Property
Taxes
1,920,000
1,770,000
1,600,000
2,090,00
2,340,000
10,000
17,100,000
38,800,000
6,290,000
7,460,000
285,746
79,665,746
2007 Net Propert Taxes
2008 Estimated Net Propert Taxes
Adjustment
69,102,427
79,665,746
10,563,319 Ref 7.2
Rocky Mountain Power PAGE 7.3
Idaho General Rate Case. December 2007
Renewable Energy Tax Credit
TOTAL IDAHO
ACCOUNl Type COMPANY FACTOR FACTOR % ALLOCATEP REF#
Adjustment to Expense:
FED Reneable Energy Tax Credit 40910 1 (10.697.164)SG 6.0479%(64.958)7.3.1
FED Renewable Energy Tax Credit 40910 2 (5,899,476)SG 6.0479%(356.797)7.3.1
FED Renewable Energy Tax Creit 40910 3 SG 6.0479%7.3.1
Mining Rescue Training Credit
40911
40911
3
(200,452)
(370.212)
(46,485l
(617,149
6.0479%(12,123)7.3.1
(22,390)7.3.1
(3,062l 7.3.2
(37,575
UT Renewable Energy Tax Credit
OR Business Energy Tax Credit
40911 3 SG
SG
SE
6.0479%
3 6.5865%
Description of Adjustment:
This adjustment normalizes federal and state renewable energy income tax credits and state tax credits the Company is
entitled to take as a result of placing qualified generating plants into service. The federal tax credit is based on the generation of
the plant. and the credit can be taken for ten years on qualifyng propert. The Utah state tax credit is based on the generation
of the plant, and the credit can be taken for four years on qualifyng propert. The Oregon BETC is based on investment of plant.
and the credit is taken over a 5 year period on qualifing propert. Mining rescue training credit is a new tax credit available for
amounts paid or incurred in tax years beginning after December 31. 2005 and before January 1, 2009 for training mine rescue
teams. Under the 2006 Tax Relief and Health Care Act. no deduction is allowed for the portion of expenses that would
otherwise have been allowable as a deduction for the tax year that is equal to the amount of the mine rescue team training credit
determined for the tax year under Code Sec. 45N.
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Page 7.3.2
Rocky Mountain Power
Idaho General Rate Case - Decmber 2007
Mining Rescue Training Credit
12131107 Provision
130.700 Ming Rescue Training Credit add back
920.145 PMI Ming Rescue Traing Credit add back
$ 28,527
$ 17,958
$ 46,485 Ref7.3
. The credit is an addback to income in the year utiize, therefore the Sch M us in the ta provision is the amount of
credit for the year.
It is assumed that the amount of credit will re unchanged for 2008
Rocky Mountain Power PAGE 7.4
Idaho General Rate Case - December 2007
SCheduleM
TOTAL IDAHO
ACCOUNlll COMPANY FACTOR FACTOR % ALLOCATED ~
Adjustment to Expense:
Schedle M Addition - Temporary SCHMAT 3 (1,673,387)WY-All Situs
Schedule M Addition - Temporary SCHMAT 3 (939,497)WY-All Situs
Schedule M Addition - Temporary SCHMAT 3 (46,940)WA Situs
Schedule M Addition - Temporary SCHMAT 3 (4,461,413)UT Situs
Schedule M Addition - Temporary SCHMAT 3 (1,249,326)10 Situs (1,249,326)
Schedule M Addition - Temporary SCHMAT 3 (333,105)CA Situs
Schedule M Addition - Temporary SCHMAT 3 (11,371,774) SCHMDEXP 5.6995%(648,137)
Schedule M Addition - Temporary SCHMAT 3 2,523,530 SE 6.5865%166,211
Schedule M Addition - Temporary SCHMAT 3 (8,358,685)SG 6.0479%(505,528)
Schedule M Addition - Temporary SCHMAT 3 (457,529)SO 5.7555%(26,333)
(26,368,126)(2,263,113)7.4.1
Schule M Deuction - Permanent SCHMDP 3 (10,900,494)SG 6.0479%(659,255)7.4.1
Schedule M Deduction - Temporary SCHMDT 3 (3,297,328)GPS 5.7555%(189,778)
Schule M Deduction - Temporary SCHMDT 3 (2,470,570)10 Situs (2,470,570)
Schule M Deduction - Temporary SCHMDT 3 (68,644)OR Situs
Schedule M Deduction -Temporary SCHMDT 3 (23,391,888)OTHER 0.0000%
Schedule M Deduction - Temporary SCHMDT 3 1,744,500 SE 6.5865%114,901
Schedule M Deduction - Temporary SCHMDT 3 (14,521,023)SG 6.0479%(878,222)
Schule M Deduction - Temporary SCHMDT 3 (994,829)SO 5.7555%(57,257)
Schedule M Deduction - Temporary SCHMDT 3 130,771,883 TAXDEPR 5.7883%7,569,532
Schedule M Deduction - Temporary SCHMDT 3 (211,234)WA Situs
87,560,867 4,088,605 7.4.1
Description of Adjustment:
Ths adjusts Schedule M's included in the filing through the Decmber 2007 test period.
7.4.1
Rocky Mountain P_
Id Generl Rae Case. December 2007
Schedule M by Alloatn Factr
12 Moths Dec 07-Dec 08
6_20 12_2008 12_208 Inc_ntal
Totl Totl Total Tot~~C9!Y ~
SCHMA.Pennanen Addits
None
Summa of SCHMA
SCHMAT.Tempora Additions
SCHMATWVP 445.28 44,428 89,856 (1.673,387)
SCHMATW 201.661 (292.697)(91.036)(939.497)
SCHMATWA 111,00 111.00 222,012 (46.94)
SCHMATU 78.014 78.014 156.028 (4.461,413)
SCHMATIDU (219.981)(219.981)(439.962)(1.49.326)
SCHMATCA (33.105)
SCHMATSCHMDEXP 242.144,639 242.144.639 48.289.278 (11,371,774)
SCHMATSE 10,751,27 11,351.012 22,102.039 2.523,5
SCHMATSG 11.576.896 8.884.079 20.46.975 (8,358.685)
SCHMATSO 7.60.307 7.616.462 15.222,769 (457,52)
Summary of SCHMAT 272.694.997 270.117.962 542,812.959 (26.368.126) Ref7.4
Total Schedule M Addltons 272,694.997 270.117,962 542.812.959 (26.36.126)
SCHMDF-Fio through DeuctNon
Sum of SCHMDF
SCHMDP-Pennt DeducnsSCHMSG (10,900.494)
Suar of SCHMDP (10,90,494) Ref7.4
SCHMDT.Temra Deucns
SCHMDTGPS 31.821.620 31,821.620 63.64.240 (3,27.32)
SCHTIOU (310.410)(310.410)(620,820)(2.470.570)
SCHMOTOR 1.06,726 1,06,726 2.133,452 (68.64)
SCHMOTOTHR 3.418,40 3.418.04 6.36.08 (23,391.88)
SCHMTSE 11,73.405 12.95.920 24.691,325 1,744.50
SCMDTSG (2,513.192)14.548 (2.498.644)(14,521.02)
SCHMDTSO 29.48.66 29.618.792 59,103.45 (9.82)
SCHMOTTAXPR 367.442.482 367,442.482 734.8.96 130.771.88
SCHMOTWA 98,240 98.240 1,96.48 (211.234)
Summary of SCHMDT 44.129.575 447.00,958 89.139.533 87,50,866 Ref 7.
Tot Scheule M Deducons 44.129.575 447.00.958 89.139,533 76.66.373
Tot Schedule M Adjustmnts (170.434.578)(176.891.99)(347.326.574)(103.28.499)
Rocky Mountain Power PAGE 7.5
Idaho General Rate Case - December 2007
Deferrd Income Tax Expense
TOTAL IDAHO
ACCOUNT Tvoe COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Deferred Incoe Tax Expense. Debit 41010 3 186,427 IBT 3.0074%5,607
Defered Incme Tax Expense. Debit 41010 3 (706,029)10 Situs (706,029)
Deferred Incoe Tax Exense. Debit 41010 3 (26,049)OR Situs
Deferred Incoe Tax Expense. Debit 41010 3 (9,524,037)OTHER 0.0000%
Deferred Incoe Tax Expense. Debit 41010 3 (82,338)SE 6.5865%(5,423)
Deferred Ince Tax Expense. Debit 41010 3 (7,705,558)SG 6.0479%(466,027)
Deferred Income Tax Expense. Debit 41010 3 (4,981,211)SO 5.7555%(286,693)
Deferr Income Tax Expense. Debit 41010 3 (80,164)WA Situs
Deferred Income Tax Expense. Debit 41010 3 38,663,371 DITEXP 6.1389%2,373,505
15,744,412 914,939 7.5.1
Defered Income Tax Expense. Credit 41110 3 126,416 CA Situs
Defered Income Tax Expense - Creit 41110 3 300,173 DGP 0.000%
Deferred Incme Tax Expense. Credit 41110 3 248,60 10 Situs 248,600
Deferred Income Tax Expense. Credit 41110 3 108,469 SE 6.5865%7,144
Deferred Income Tax Expense. Credit 41110 3 4,115,514 SG 6.0479%248,904
Deferred Income Tax Expense. Credit 41110 3 5,185,798 SO 5.7555%298,468
Deferred Income Tax Expense. Credit 41110 3 1,693,150 UT Situs
Deferre Income Tax Expense - Credit 41110 3 17,811 WA Situs
Deferred Incme Tax Expense. Credit 41110 3 991,616 WY-ALL Situs
Deferred Incme Tax Expnse. Credit 41110 3 13,768,078 DITEXP 6.1389%845,208
26,555,625 1,648,325 7.5.1
Investment Tax Credt Amrtization 41140 3 4,046,093 DGU 12.0770%488,647 7.5.1
Description of Adjustment:
Ths adjusts deferred incme tax expense incuded in the filing through the December 2007 test period.
7.5.1
Rocky Mountan Po_r
Idah General Rate Case. Deember 207
Total Defeed Tax Expens by Alloaton Fac
12 Monts IncrementalJunoe-0 De-0 chang betwen
Tot Tot Totl De_2oo7Al~~~an De 2008
Deerr Inom Tax - Debi !W
41010IBT 176.165 131.461 307.626 186.427
41010lDU 6.58.515 6.583.515 13.167.030 (706.029)
410100R 67.049.913 67.04.913 134.099.826 (26.04)
410100THER 1.107.521 1.107.521 2.215.042 (9.524.037)
410105E 3.52.515 3.522.515 7.04.030 (82.338)
410105G (49.018)461.285 (36.733)(7.705.55)
4101050 16.292.63 16.343.541 32.63.180 (4.981.211)
41010WA 12.578.027 12.578.027 25.156.054 (80.164)
41 01 OOrrP 19.331.68 19.331.686 38.66.371 38.66.371
Totl De In Tax - Debit 126.143.962 127.109.464 253.253.427 15.744.413 Ref 7.5
Derr Inc Tax - Creit !1
41110CA (4.658.64)(4.65.64)(9.317.29)126.416
41110DGP 30.173
411101 (5.578.289)(5.578.289)(11.156.578)248.600
411105E (3.77.254)(3.54.515)(7.321.769)108,469
411105G (3.969.929)(2.947.978)(6.917.90)4.115.514
4111050 (8.527.173)(8.531.027)(17.058.199)5.185.798
41110U (40.04.313)(40.044.313)(80.08.626)1.693.150
41110WA (10.326.031 )(10.326.031 )(20.652.062)17.811
41110WP (22.20.778)(22.022.165)(44.231.94)991.616
41110DEX 6.88.039 6.884.039 13.768.078 13.768.078
Tot De Inc Tax . Crit (92.20.376)(90.767.926)(182.976.301 )26,555,625 Ref 7.5
Tot De Ine Tax Ex 33.935.587 36.341.538 70.277.125 42.30.037
Intm Tax Cre Amza 41140DG (90.38)(90.384)(1.80.767)4,04.093 Ref 7.5
Rocky Mountain Power PAGE 7.6
Idaho General Rate Case. December 2007
Page 1 . Deferred Income Tax Balance
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Accmulated Deferred Income Taxes 190 3 (1.887,380)BADDEBT 3.6079%(68.094)
Accumulated Deferred Income Taxes 190 3 (23.570)CA Situs
Acumulated Deferred Income Taxes 190 3 (23.818)CN 4.0638%(968)
Accumulated Deferred Income Taxes 190 3 (2,438)DGP 0.0000%
Accumulated Deferred Incoe Taxes 190 3 740,424 IBT 3.0074%22.268
Accmulated Defered Income Taxes 190 3 (175.772)10 Situs (175.772)
Acmulated Deferrd Income Taxes 190 3 18.446 OR Situs
Accmulated Deferred Income Taxes 190 3 26.922 OTHER 0.000%
Accmulated Defered Income Taxes 190 3 15,142.619 SE 6.5865%997,363
Acumulated Deferred Income Taxes 190 3 4.340.141 SG 6.0479%262,489
Accmulated Deferred Income Taxes 190 3 (21.316)SNP 5.6349%(1.201)
Acumulated Deferred Incme Taxes 190 3 17.222 SNPD 4.6825%806
Accmulated Deferred Income Taxes 190 3 25.645.993 SO 5.7555%1,476.054
Accumulated Deerred Income Taxes 190 3 2.505.336 SSGCT 6.1504%154.088
Acmulated Deferred Income Taxes 190 3 (14.660)TROJD 6.1442%(901)
Accumulated Deferred Income Taxes 190 3 (4.199.608)UT Situs
Accumulated Deferred Income Taxes 190 3 (76,200)WA Situs
Accmulated Deferred Income Taxes 190 3 303.539 WY-ALL Situs
42,315.880 2.666.133 7.6.1
Accmulated Deferred Income Taxes 282 3 (35.460,803)CA Situs
Accumulated Deferred Income Taxes 282 3 1,266,430,443 DITBAL 6.2599%79.277,282
Accmulated Deferred Incme Taxes 282 3 (3.107.769)FERC Situs
Acumulated Deferred Income Taxes 282 3 (1.002)GPS 5.7555%(58)
Accmulated Deferred Income Taxes 282 3 (83.432.380)10 Situs (83,432.380)
Accmulated Deferred Income Taxes 282 3 (389.745.617)OR Situs
Acmulated Deferr Income Taxes 282 3 (746.834)SE 6.5865%(49,190)
Acumulated Deferred Income Taxes 282 3 (1.124.304)SG 6.0479%(67.997)
Acumulated Deferred Income Taxes 282 3 (2.583.468)SO 5.7555%(148.691)
Acumulated Deferred Income Taxes 282 3 (591.294.107)UT Situs
Accmulated Deferred Incme Taxes 282 3 (90.557.338)WA Situs
Accumulated Deferred Income Taxes 282 3 (138,304.788)WY-ALL Situs
Accumulated Deferred Income Taxes 282 3 (26,757.744)WY-ALL Situs
(96.685.711)(4.421.034)7.6.1
Description of Adjustment:
This adjusts the deferred income tax balances included in the filing through the Decber 2007 test period.
Roc Mountin Power Pa 7,6,1
Id Gel Rate Cas. Decbe 207
Def Tax.. By Balance She Açeunt By AUocion Factr In
YeaEn YeaEn ch beBancBalDe_207ilI2amDe 20
Accu!a Pe Tax Acnt 19019OEBT 1.89.60 95.115 (1.887.38)190 50,915 39.130 (23.570)
190N 100,2 88 (23.818)190P (851)(2.070)(2.43)
190T 871,8 740.424 740.42419O422.020 33.38 (175.n2)190 821.08 83,3 18.44
190THER 4,99.924 5.012,3 26.92
19O 33.072.99 32,498.80 15.142.819
19O 45.43,524 46.818.96 4.3.141
190G-190G-
190NP (10.85)(21.316)(21.316)
190NPO ns.8 784,420 17.22
1900 71.468.65 65.92.857 25.64.99
190GCT 3.75.003 5.010.671 2.50,3
190TROJO (7.193)(14,52)(14.68)190 (1.85.817)(3.95.621 )(4.199.60)
190A 29.60 258,50 (7.2)190 1.371.887 1,429.83 303.539
Tot Acc 190 163,471.849 158.530.620 42,315.880 Ref 7.6
Acculat Pe Tax Account 281No
Tot Acc 281
Acmu Pe Tax Ac 2828 (34.59,5)(3.480.803)(3548.80)
28DG262BAl (19.56.942)(45.782.68)1.2.43.44
282ERC (3.03.03)(3.113.62)(3.107.76)
282PS (501)(1.102)(1.002)28 (82.90.926)(83,91.449)(83.4338)28R (379.375.138)(38.85.69)(3.745.817)
282THER (3.961.218)(3.961.218)282 (13.44.86)(13.817.282)(748.83)
282SG (8.951.719)(9.S13.870)(1,124.30)280 (15.89,277 (17.185.011)(2.58.46)28 (58.819.58)(591.2.107)(59 .2.107)28A (8863,38)(90.557.33)(90.55,3)28 (134.20.001)(138.30.788)(138.30.78)282 (26.48.224)(26.757,744)(26.757.744)
Tot Accnt 282 (1,394.870,386)(1,449.547,597)(96.685.711) Ref 7.
Aculat Pe Tax Acc 2828 (72.08)(79.96)(17,89)28PS (13.79.30)(13.52,54)531,58
28310U (53.84)(52.151)69.11128(4.08.98)(2,90.50)2.33.015
283THER (29.410,77)(3.79.79)(8.78038)28E (15.83,531)(14.73.143)1.981.076
28G (9,59.078)(8.141.822)1.587.58
283GC (2.72.65)(2,551.54)35.22
283NP (7,061.151)(8.178.48)1.78.374283(5.074.010)(5.31.50)(83,98)
283TROJO 470.86 781.68 581.8328(878.34)(96.742)748.971
283A (1.819.239)(2,614.974)(1.52.119)
283WY 33,2
283WY
283NUTIL 115.787 231.574 231.574
Tot Ac 283 (90,456.346)(90,66.88)179,283 Ref 7.7
Tot Accte De Inc Tax (1.321.85.88)(1,383.68,85)(54,190.547)
Acculat Pe Ta Acc 25
255rTC8 (2.62.961)(2,33.05 56.60
255C8 (3.970.58)(3,59.470)86.z
255rTC8 (1.m.76)(1.58.S21)38.48
255C8 (25.931)(226.38)55.14225C8(54.373)(48.158)118,43
25rTC90 (3.68)(30.302)73.156
25IBT (2.429,740)(2.429.740)(2.429,740)
Tot Accnt 255 (11,940,237)(10,907,608)(36482) Ref 7.7
Rocky Mountain Power PAGE 7.7
Idaho General Rate Case. December 2007
Page 2 . Deferred Income Tax Balance
TOTAL IDAHO
ACCOUNl Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Accmulated Deferred Income Taxes 283 3 (17,894)CA Situs
Accmulated Deferred Income Taxes 283 3 531,558 GPS 5.7555%30,594
Accumulated Deferred Income Taxes 283 3 698,111 10 Situs 698,111
Accmulated Deerred Income Taxes 283 3 2,335,015 OR Situs
Accumulated Deferred Income Taxes 283 3 (8,768,038)OTHER 0.~~%
Accmulated Deferred Income Taxes 283 3 1,981,076 SE 6.5865%130,483
Accumulated Deferred Income Taxes 283 3 1,567,588 SG 6.0479%94,807
Accmulated Deferred Income Taxes 283 3 356,220 SGCT 6.0719%21,629
Accmulated Defered Income Taxes 283 3 1,765,374 SNP 5.639%99,477
Accmulated Deferred Income Taxes 283 3 (634,988)SO 5.7555%(36,547)
Accmulated Deferred Income Taxes 283 3 581,632 TROJD 6.1442%35,737
Accmulated Defered Income Taxes 283 3 746,971 UT Situs
Acculated Defered Income Taxes 283 3 (1,529,119)WA Situs
Accumulated Deferred Income Taxes 283 3 334,204 WY-ALL Situs
Accmulated Deferred Income Taxes 283 3 231,574 NUTIL 0.000%
179,284 1,074,290 7.6.1
Accumulated Investment Tax Credit 255 3 569,808 ITC84 0.0000%
Accmulated Investment Tax Creit 255 3 862,236 ITC85 0.0000%
Acumulated Investment Tax Credit 255 3 386,486 ITC86 0.0000%
Acmulated Investment Tax Credit 255 3 55,142 ITC88 0.0000%
Acumulated Investment Tax Credit 255 3 118,430 ITC89 0.~~%
Accmulated Investment Tax Credit 255 3 73,156 ITC90 13.9815%10,228
Accumulated Investment Tax Credit 255 3 (2,429,740)IBT 3.0074%(73,073)
(364,482)(62,845)7.6.1
Description of Adjustment:
This adjusts the deferred income tax balances included in the filing throgh the Decber 2007 test period.Ii
8
DAH RE PRTO Pa 8.0 Tot
Ms Rate Ba Ad (Tab 8t
TOTAl
8.1 8.2 8.3 8.4 8.5 8.6 8.7EnlaCusio
Upate Ca Upp Bever Amn Fo Po Hyro GoCr se Adv_fo
Tot Noed Worinii C8I Hyro Sale Hy Real Deis Tra (PRCO)Co
1 0p Reenes:2 Gel Bu Rees3 InI4 Spe Sa
5 0I Opli Reenues
6 Toll Opli Re
7
8 0p Ex:II Stem Pr10 Nur Pruc11 Hy Pruc (9.467)(5,21t (23)(4.032)
12 0I Po SUly13 Tra
14 Dltr15 Cu Acnt16 Cus Se & Info
17 Sa18 Admiti & Geer
19 Toll O&M Ex (9,467)(5,231)(203)(4.03)20 De (33,287)(3,386)(18.643)(13,29)21 Amti 98.55 98.55
22 T_ 0I Than In
23 In T_: Feal (6.491)3,251 5.829 (27,157)11,787
24 Sta (882)442 765 (3.890)1.802
25 De In Taxes
26 Inimt Tax Ct Adl
27 Mi Reen & Exse (38.392)(1.113)(35,279)
28 Tot Opli Exse:12.054 (6.37)(10.53)50,435 (21,890)
29
30 Opti Re Fo Re (12.054)a.37 10,453 (50,43)21.90
31
32 Ra Ba:
33 EI Pl In Ser 70.853824 (83)
34 Plt He fo Fu Us (802.985)35 Mi De 0e (68.181)(68.181)
38 El Pl Ac Adi
37 Nucl Fu
38 Praymts
39 Fue St 1.78.824
40 Mate & Suplie
41 Wor Capl (831411)1,2.84
42 Weallti Lons
43 Mi Rate Ba
44 Tot EI Pl 70.998,333 1,23,8 (68.181)(63.234)
45
46 ll:47 Ac Pr Fo De 40.081 40.081
48 Ac Pr For Am
49 Ac Deln Tax50 tJ IT
51 Cusio /l For Cot (38.825)(388.25)52 Cu Se De53 Mine De (937.541)(52.819)(8&"'22)
54
55 Tot Oe (l.26a.64)(12.837)(864.82)(36.825)
56
57 Tot Rate Ba:69.732.249 1,2.84 (68.181)(76.71)(88.82)(38.25)
58
5980 Este ROE im .1.50%-003 0.00 0.04%.(.018%0.011%0.02 0.00%
61
62
63
64 TAX CACULATIO
8566 Opti Reue (19,27)8.730 18.46 (81,282)35,27987 0I De
68 In (AFUDC)
69 Intet70 SCll'M" Addi71 Schule 'V De
72 In il Tax (19,427)9.730 16.846 (81,282)35,279
73
74 State In Taxe (882t 442 785 (3.890)1.602
75
76 Taxle Inco (18.545)90288 16.081 (77,592)33,677
n
76 Fel In T_(6.491)3,251 5.82 (27.157)11,787
IDREVD PROL Pa 8.0.1 Tot
io Rate Bae Ad (Tal
TOTAL
8.8 8.9 8.10 8.11 8.12 0 0 0
Trapp Mi Ra .1 Br Mi Mine Pr Foi Ma
Bae Ra Base Rate Ba Plnt Ad FEC 105 (PHFU)0 0 0
1 Opti Reen.-2 Gel Bu Reue3 Inepart4 Sp sale5 Oter Optig Re
6 Tot Op Reues
7
8 Opti ex:9 Ste Pruc10 Nur Pr11 ~ro Pr
12 Ot Po Suppl13 Trasm14 D11r15 Cuto Ai16 Cuto S8ic & In
17 Sa18 Admiis & Ge
19 Totl Q&U Exse20 De21 Amti22 T_OtTh Inco23 In T_: Fed
24 Sl25 De In T_26 Intm Tax Cr. Adj.27 Ui ~ & Ex
28 Tot Opg Ex
29
30 Op Re Fo Re
31
32 Ra Base: 33 ei Pl in Se 411.30 11.071.450 59.43.3
34 Plnt He ro Fut Us (82.985)
35 Ui De De
36 EI Pl Ac Ad37~Fue38 FW)'
39 Fu St 1.078.24
40 Mal & Sup
41 Worin Csll (1,2,93)42 Wtørti Lo
43 Ms Rate Ba
44 Tot El Pl 411,303 11.071,450 (217.169)59.434,305 (802,985)
45
46 De47 Ac Pr For De
48 Ac Pr For Am
49 Ac De In Tax
50 IJ rrc51 Cu Al Fo CDI52 Cu Se De53 Ms Deuc
54
55 Tot De:
58
57 Tol Ra Ba 411.30 11.071.45 (217.169)59.434,305 (80.985)
58
5960 Esli RO im ~.010%~.2%0.00%-1.3%0.02 O.ll 0.0%O.ll
61
62
63
64 TAX CATI
6566 0p Re67 Ot Dect
66 in (AFDC)
69 intet
70 SCedle.M" Ads71 Sch "U De
72 In Be Tax
73
74 Sl In Taxes
75
76 Taxle Inn
78 Fel In T_
Rocky Mountain Power PAGE 8.1
Idaho General Rate Case. December 2007
Update Cash Working Capital
TOTAL IDAHO
ACCOUN1~COMPANY FACTOR FACTOR % ALLOCATED B&
Adjustment to Rate Base:
Cash Working Capital CWC 1 63,075 10 Situs 63,075
Cash Working Capital CWC 2 (8,363)10 Situs (8,363)
Cash Woring Capital CWC 3 1,178,132 10 Situs 1,178,132
1,232,844 1,232,844
Adjustment Detail:
Type1 Typ 2 Type 3
O&M Expense 179,932,011 180,021,377 271,345,834 1.1
Taxes Oter Thn Incme Tax 4,503,690 4,503,690 5,111,661 1.1
Federl Income Tax 2,870,310 2,179,480 1,410,671 1.1
State Ince Tax 538,99 493,60 45,921 1.1
Less: Embedded Cost Diferential (7,028,078)(7,028,078)(7,028,078)
Total 180,816,923 180,170,068 271,295,008
Divided by Days in Year 365 365 365
Average Daily Cost of Service 495,389 493,617 743,274
Net Lag Days 4.72 4.72 4.72
Cash Woring Capital 2,331,138 2,329.315 3,501,507
Unadjusted Cash Working Capital 2,274,663 2,337,738 2,329,375
Cash Woring Capital Adjustent 63,015 (8,363)1,118,132
DescriptIon of Adiustment:
This adjustment is necessary to compute the cash working capital for the nonnalized results made in this filing. Cash
working capital is calculated by taking total operation and maintenance expense allocted to the junsdicton (excluding
depreciation and amortization) and adding its share of allocated taxes, including state and federal income taxes and taxes
other than incoe. This total is divided by the number of days in the year to detennine the Company's average daily cost of
service. The daily cost of service is multiplied by net lag days to produce the adjusted cash working capital balance. Net lag
days are calculated using the Company's December 2007 lead lag study. The Lead/Lag days for Idaho were calculated as
being 4.72 days.
Rocky Mountain Power PAGE 8.2
Idaho General Rate Case. December 2007
Upper Beaver Hydro Sale
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
l'djustment to Expense:
Misc. Hydro Expenses 539 1 (96,58)SG-U 6.048%(5,841)8.2.1
Maintenan of Strctures 540 1 (90)SG-U 6.04%(5)8.2.1
Maintenanc of Dam & Waterway 542 1 (647)SG-U 6.048%(39)8.2.1
Maintenance of Dam & Wateray 543 1 10,824 SG-U 6.048%655 8.2.1
Maintenanc Hydro-Other 544 1 (1)SG-U 6.04%
(5,2~~l
8.2.1
(86,497)
Adjustment to Depreciation Expense:
Hydro Deprecation 403HP 1 (42,557)SG.U 6.048%(2,574)
Transmissio Deprection 403TP 1 (8,687)SG 6.04%(525)
Genral Plant Deecation 403GP 1 (4,739)SG 6.048%(287)
(55,982)(3,386)
Recognition of Gain:
Los on sale of prope 421 1 (18,398)SG 6.048%(1,113)
Description of Adjustment:
The Company entered into an agreement to sell the Upper Beaver hydro electric facilties to Beaver City, Utah. The sale
close on September 14, 2007. This adjustment removes the Upper Beaver assoated expenses such as depreiation and
O&M.
Rocky Mountain Power
Idaho General Rate Case December 2007
Upper Beaver Hydro Facilties Sale
Rate Base (Assets Retired)
Transportation Equipment
Reservoirs, Dams & Waterways
Station Equipment
Electric Plant in Service
Operations & Maintenance
Misc Hydro Power Generation Exp
Maintenance of Structure
Maintenance of Dams & Waterways
Maintenance of Dams & Waterways
Maintenance Hydro - Other
Total Operations & Maintenance
Loss on Sale
Balance Balance
1213112006 12131/2007
97,694
2,570,160
685,155
3,353,009
539
540
542
543
54
96,583
90
647
(10,824)
1
86,497
18,398
Page 8.2.1
Ref 8.2
Ref 8.2
Rocky Mountain Power PAGE 8.3
Idaho General Rate Case - December 2007
American Fork Hydro Removal
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Misc. Hydro Expenses 539 1 (3,364)SG-U 6.048%(203)8.3.1
Adjustment to Depreciation Expense:Hydro Deiation 403HP 1
Hydro Depreciation 403364 1
(275,182)
(120l
(275,302
SG-U
UT
6.048%
Situs
(16,643) 8.3.1
8.3.1
(16,643)
Description of Adjustment:
The Amencan Fork hydro elecnc plant was retired as of September 2007. This adjustment removes the Amercan Fork
depreciation and O&M expenses.
Rocky Mountain Power
Idaho General Rate Case December 2007
American Fork Hydro Removal
Rate Base (Assets Retired)
Hydro Plant
Intangible Plant
Distribution Plant
Hydro Plant Accum Depr*
Intangible Plant Amortization
Distribution Plant Accum Depr
O&M
Misc. Hydro Expenses
Depreciation
Depreciation - Hydro Plant
Depreciation - Dist Plant
Facor
SG-U
SG-U
UT
SG-U
SG-U
UT
Balance
Dec 06
1,001,227
462,400
6,821
1,470,448
(1,450,324)
(462,400)
(4,219)
(1,916,943)
539
403HP
403364
Balance
Dec 07
SG-U
SG-U
UT
*Reclamation balance accrued included in accumulated depreciation reserve.
Page 8.3.1
3,36 . Ref. 8.3
275,182
120
275,302 Ref. 8.3
Rocky Mountain Power PAGE 8.4
Idaho General Rate Case - December 2007
Powerdale Hydro Decommission
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Intangible Plant Amortzation 4041P 1 (248,803)SG-P 6.048%(15,047)
Hydro Plant Depreciation 403HP 1 (218,893)SG-P 6.048%(13,239)
(467.696)(28,286)8.4.1
HydroO&M 539 1 (66,672)SG-P 6.048%(4,032)8.4.1
Adjustment to Unrecovered Plant:
Unrecvered Plant Amortization 407 1 (780,128)SG-P 6.048%(47,182)8.4.2
Unrevered Plant Amortization 4041P 3 2,654,642 SG-P 6.048%160,551 8.4.2
Unrecovered Plant Reg Asset 182M 3 (1,327,321 )SG-P 6.048%(80,276)8.4.2
Decmmissioning Reg Asset:
Decmmissioning Amortization
Decmmissioning Reg Asset
4041P
182M
3
3
3,824
199,973
SG-P
SG-P
6.048%
6.048%
231 8.4.3
12,094 8.4.3
Description of Adjustment:
This adjustment reflecs the tratment approved by the Commission to account for the decmmissioning of the Powerdale
hydrolecmc plant due to damage caused by a flood in November 2006. During 2007, the net book value (including an offset
for insuranc proeds) of the assets to be retired was transferred to the unrecvered plant reulatory asset. In addition,
fure decommissioning costs wil be deferred as they are spent and amortized over ten years, beginning in the subsequent
year after they are spent.
Pag 8.4.1
Rocky Mountain Power
Idaho General Rate Case December 2007
Powerdale Removal
12ME
Description Account Factor Dec 2007 Expense Ongoing Expense Expense to Remove Ref
Depreciation Expense
Intangible Plant 4041P SG-P 248,803 248,803
Hydro Plant 403HP SG-P 5 5
Hydro Plant 403HP SG-P 10,774 10,774
Hydro Plant 403HP SG.p 181,341 181,341
Hydro Plant 403HP SG.p 19,372 19,372
Hydro Plant 403HP SG.p 6,286 6,286
Hydro Plant 403HP SG.p 401 401
Hydro Plant 403HP SG.p 714 714
467,696 467,696 Ref 8.4
Operation & Maintenance
OPER SUPERV & ENG 535 SG-P 7,569 7,569
HYDRO/OTH REC FAC 537 SG-P 10,284 10,284
MSC HYD PWR GEN EX 539 SG-P 103,048 72,00 31,04
MNT DAMS & WTR SYS 543 SG-P 722 722
ACCESS ELEC EQUIP 54 SG.p 1,592 1,592
MAINT HYDRO-OTHER 545 SG-P 15.457 15,457
138,672 72,000 66,672 Ref 8.4
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Rocky Mountain Power PAGE 8.5
Idaho General Rate Case. December 2007
Goose Creek Transmission
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Remove CY 2007 Balances:
Transmission Plant In Service 350 1 (656,211)SG 6.04%(39,687)8.5.1
Accm. Provo for Depr 108TP 1 433,091 SG 6.048%26,193 8.5.1
Remove Future Retirement:
Transmission Plant In Service 350 1 (432,913)SG 6.048%(26,182)8.5.1
Accum. Provo for Depr 108TP 1 229,638 SG 6.048%13,88 8.5.1
Transmission Plant Additions:
Construction of Yellowil line 350 3 43,581 .SG 6.048%2,636
Gain on Sale of Transmission Assets:
Unamortized Gain Balance 254 3 (874,987)SG 6.048%(52,919)8.5.3
Gain on Sale of Transmission Asi 421 3 (583,324)SG 6.04%(35,279)8.5.2
Description of Adjustment:
On April 1, 2008, the Company sold 13.85 miles of trnsmission line, running from the Company's Goose Creek switching
sttion and extending norh to the Decker 230 kV substation near Decker, Montana. Assets sold included structures,
miscellaneous support equipment, easements and rights-of-way associated with the transmission line. The sale of the
trnsmission line resulted in the Goose Creek swtching station no longer being useful to the Company. In the summer of
2008, the Company plans to remove the Goose Creek swtching station including all above ground facilities and level the
site. After removing the swching station, the Company will build a short segment of 230 kV transmission line to ensure
continued operation of its Sheridan to Yellowtail 230 kV transmission line. This adjustment amorzes the net gain
assoiated with the sale over three years, reduces rate base by the net book value of the assets sold and adds the new
Yeilowailline asset into rate base. The Company notified the Idaho Commission of the planned sale of this utilty
trnsmission plant facility in a letter dated August 21,2007.
.
Rocky Mountain Power
Idaho General Rate Case December 2007
Gooe Crek Transmision Sale
Pag 8.5.1
Report date. 12/31/2007
created OI. 04/28/2008
ABIM Baance (curent BOk valuel - 01 Il Deree.2
.w.=.
b)$laag"~;š%¿?!j~ff~~jj~"'ií~~:äl:~pl~~~i~.jilg~~:~E4f~;gt..'.;~\' ;,!~~sli~l;..;Ä)'0if£;t;;U:t1l&:liE; ..,..,:;~tlM:l¡;.~.,
:$'l)~4~;,;,Rj¡çd:#'Ìw~~l;f;t;:äl~g,¡.~~ii'i~~~L.~l~~~",.;;;;r¡~.fl;;ê,~¡;~;it;I;,t:!!E;tft;Jl¡~~l::::,; ..; ?:;t~¡,;~:.:;;;;=.;
:i."¡~tig~;:it~$i~;,v,"~'Wt'*,"èlint~;~~i~~.'=~~Íirei'1 ;...~.,.;';: !??~:e:;t¿:~l':;t,);$:;§;~~;~~=~:ä;;i. .;.i.,;¿~s,l~ä:~ ".,~..
;,,;~::tŠ!;':::t;~~t:;:::;::~il~:tiftt¡.'Iiri:;' \+;':::~~~:'::~~t;;Rti¡!;;j::,;:.f;,~i~Kriai:;',;'t:;l;'ü';li:d$'
.1000 20 iuiu G5G.210 GO l33.0g1 1p.22),111 l1 OSD
*-1000 20 G5G.210 GO lU,OP1 11-U3,11g l1 OS
*..1000 G5G,210 GO U),OP1 1P-223,11g.l1 US
..."1000 G5G,210 60 U3.01l lP-U),l1P l1 US/
Net Bo Val . Trasmissin Un - To 8.5.2
__ ..., 12/)1/i007 b_. 1l_.. (Q... _ .,ai_i - 01 - Da*..
Or_"".., W2I/iOO8
;:~.,;¡i~,.~''!~íli'~'Ä~~'r~N:!;','i~'''''i~~''~~~'''': ',' ~ .,.;;"':,",,.'~_S':.';"fi:': ~~i:;;';' ,'; ,,:,,';;ni~:;;:::.'
;:':::::~:t~~;i.f;~~,::\'~f;:r?t~:~':'t~~?'~~:E~¡/:;;:i\;Z:~L~;';t~J;,~.~~~,:-;:-'r-t~t,:';~3H~~\: 1J,':;:i,~;;'r~~::~t~~~:~:,~'iiiil:';tt;':~:~i:':tt-t'-:i,'t;;'Jli~,:; .~'.'::'';':: ?Ù::-u-~~'di;;:~y:;¡-'
"ö=,,,~,;,:i:'&'~.iG,;~,,~:~,,;A:i;,;,(,;~~,~m~,,,,:, ;;'~i;.:.i,'.;. ~ ;"ò,'''Wiüi¡jj:: .."''''';'';i'ik::.' .,,',,;', :,n;:::'~::"
',d~::;,:,;y' ",:;::'''i'!~ d;'i';L~::;,\,' ~~~¡'Z.lrj~~~S,/,.... ,-,'" .:",:i.M;:.~t~, ':':; '?i:¡~:::i :"':~:;~;;~ ': "
:\~\~~i::i~'::~t/~;'zi;;;:'~~;~l;~.:~f,i:~:~S'~:~':iiS:~;):llit~,;tfHm~~~~š't;:i:£i:;:!;qL"""_N:,::'t:l:;;~6D:~~l;:ll~: "v_ .~~:~.~.::i,,::t::-::,:=,-:g:.-::, ::'f(
',;!8,~:,~;ti.&t~'.;~~';t*tUlt):;ù ';,;Jäi.,::t~:~l~~~ ..;;'7';"..)''' ;i':;'~\i?~~t~f'~JH?~~~;:l:t;:;'::':4~¡;:;~=;;
. 1000 20 U0140 .a2 in "220..110 70-20 7".' US
i:~~,l~.d~~~~~*~~~~itr)'~:".'!":¿""~":.'rfi'¡t:r.:øIt¡§~;~o:1i.1J:;'i~¡;:' ,;t;'';;;',Xt;;;..::,:;¡;.,;¡,
. 1000 n 1&0210 10.0n 27 8.'37 ,..'"'' US
.. 1000
.... 1000 .-
n &U .12 .2 Z2..~ia.21.2O.:i'i. u va
4J2 .12 82 Z2. na.:i8.:iOJ:in n US
....iooo 4i2 .u .i U. ~21 u-20 .2n.n US/
Net Boo Valu - Swin Statin - To 8.5.2
Rocky Mountain Power
Idaho General Rate Case December 2007
Goose Creek Transmission Sale
Calculation of Gain & Rate Base Addition
Proceeds from Sale:
Gross proceeds from sale
Closing Costs (tax proration & legal)
Net Proceeds from Sale
Less: Bok Value of Transmission Line Sold
Book Value Dec 31, 2007
Depreciation for January 1, 2008 - April 1, 2008
Total Book Value as of April 1, 2008
Less: Book Value of Switching Station
Book Value Dec 31,2007
Dereciation for January 1, 2008 - April 1, 2008
Total Book Value as of April 1, 2008
Less: Cost to Remove Switching Station
Est. Cost of Removing Switiching Station
NET GAIN ON SALE OF TRASMISSION LINE ASSETS
Monthly Amortization of Gain on Sale - 36 Months
April 2008 through December 2008 (9 mos (g $64,814 per mol
Yellow Tail Rate Base Addition
Total estimated cost of Yellowtail addition
BegEnd Average
Page 8.5.2
2,881,832
(32,680)
2,849,152
(223,119)To 8.5.1
3,168
(219,951)
(203,275)To 8.5.1
2,122
(201,153)
(94,750)
2,333,298
64,814
583,324 To 8.5
87,162
43,581 To 8.5
Rocky Mountain Power Page S.5.3
Idaho General Rate Case December 2007
Goose Creek Transmission Sale
3 Year Amortization Schedule
Date
Total Gain 2,333,298
Amrtzation
Unamortized
Balance
Jan-oS ..
Feb-oS ..
Mar-GS ..
Apr-oS 64,S14 2,26S,4S4
May-GS 64,S14 2,203,670
Jun-GS 64,S14 2,13S,S56 ': Average =$S74,987 I
Jul-GS 64,S14 2,074,043
Aug-GS 64,814 2,009,229
Sep-GS 64,S14 1,94,415
Oct-GS 64,S14 1,S79,601
Nov-GS 64,814 1,814,7S7
Dec-GS 64,S14 1,749,973
Jan-09
Feb-09
Mar-09
Apr-09
May-09
Jun-09
Jul-09
Aug-09
Sep-09
Oct-09
Nov-09
Dec-09
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
Jan-11
Feb-11
Mar-11
64,814
64,814
64.814
64.814
64,814
64,814
64,814
64,814
64,814
64,814
64.814
64,814
64,814
64,814
64,814
64.814
64,814
64,814
64,814
64,814
64,814
64,814
64,814
64,814
64,814
64.814
64,814
1,685,160
1,620,346
1,555,532
1,490,718
1,425,904
1,361,090
1,296,277
1,231,463
1,166,649
1,101,835
1,037,021
972,207
907,394
842.580
m.766
712,952
648.138
583,324
518,511
453,697
388,883
324,069
259,255
194,441
129,628
64,814
(0)
Rocky Mountain Power PAGE 8.6
Idaho General Rate Case. December 2007
Environmental Settlement (PERCO)
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Unspnt Envirmental Prods 25399 1 (15.370,045)SO 5.755%(884,622)8.6.2
Description of Adjustment:
PaciCorp received an insurance settlement of $38 milion for environmental clean-up projects. These funds were
trnsferr to a subsidiary called PacifiCorp Environmental Remediation Company (PERCO). This adjustment reduces rate
base by the amount of unspent cash proceeds on regulated projects from the insurance settement.
Rocky Mountain Power Page 8.6.1
Idaho Genera Rate Case - December 2007
Environmental Settement
PacifiCorp Environmental Remeiation Co.
Spnding by Envintal pro
cash Reining Actal Ac Remai
Reved cash Spnding Spendin Cash
Sie WBS 199 & after at 12/1/2006 Jan-un07 July- De 07 at 12/1127
Americn Barrel PERC/1997/E11 2,134,194 979,136 145.390 145,847 687,899
Astona 1 Unol PERc/1997/E1oo2 1,424,380 34,747 (35.258)91,807 284,198
Eugene - PaciCorp PERc/1997/E103 892,622 612,847 11,396 8,530 59,721
Everett - PacCorp PERc/1997IEoo4 1,23,143 1,587,189 22 1,587,166
Jordan 1 Barbr Tar PERc/1997/E1oo5 86,363 823,735 823,735
Ogen PERC/19971E00 1.398,531 1,329,655 1,329,655
Tacoa A Stret PERCI1997IEoo7 2,08,254 1,452,612 55 1,452,057
Tacoa River Street PERC/1997/E1008 1,213,635 159.567 159,567
Brdger GW Sampling PERCI1997/E19 36,495 (110.208)36,082 9,980 (158,270)
Brdgr Landll Repermitting PERCI1997/E1010 31.539 (20,331)22 (20,35)
Brdger Oil Spill PERC1997/E1011 791,372 416,970 416,970
carbn Fuel Oi PERC19971E012 26,034 10.253 10.253
Carbn Landfill Permit PERC/1997/E113 179.06 156,026 156,026
Can Emer. Gen. Remediation PERc/19971E014 41,756 25,158 25,158
Centlia Heavy Equipment Shop PERC/1997/E1013 71,023 68,643 68.843
Dave Joston GW Sampling PERC/1997/E1016 311,657 104,635 6,017 18.542 80,076
Dave Johnston Landfll Repermit PERC/1997/E1017 133,391 64,030 4,078 59,952
Dave Johnston Diesel Release PERC/1997/E1018 5,085 4.557 4,557
Da Johnston Lall Closure PERC/19971E019 1,310,425 1,04,951 1,04,951
Dave Johnston Landll Recamation PERc/1997/E1020 475,080 186.890 186,89
Farm GW Monionn - Hunter PERC/19971E021 221,036 9.244 13,504 9,284 (13,54)
Farm GW Motoring - Huntingon PERc/1997/E1022 194,267 (21.905)19.076 37,831 (78,813)
Hunter Fuel 011 PERCI1997/E1023 101,696 69,94 16,193 53,755
Huter Injecn Wells PERc/1997/E1024 53,45 225,566 22,011 (229)203,784
Huner Lafill Permit PERC/1997/E1025 132,745 76,818 895 92 75,831
Huntington Injection Wells PERC/1997/E1026 85,595 84,179 84,179
. Huntingon Landfll Closur PERCI19971E027 706,819 72,378 239 416,072 (34,93)
Huntngton laill Permit PERc/1997/E1028 193,883 148,56 1,66 146,89
Hun Led Paint Removal PERC/19971E029 1,00,804 (314,66)(314,66)
Hutington Wellhead Prtection PERC/19971E03O 9,84 (4,206)(4,20)
Bur Pitch PERC/19971E031 50,84 (27,598)(27,59)
Tank Farm PEC/19971E032 152,868 140,245 479 239 139,527
Naughton FGD Pond Closure PERc/1997/E1033 362,166 84,763 50.34 1,932 32.48
Naughton GW Monitonng PERCI1997/E1034 351,477 128,686 11,53 23,581 93,573
Naughton LandH Repermit PERC/19971E035 63,664 33,653 33.65
Naughton Landll Closure PERC/1997/E1036 63,814 57,839 57.839
Wyoak Pond Stud PERc/1997/E1037 100,972 31,249 2,084 5,231 23,935
Wyak Fue Oil PERC/1997/E138 20,196 1n.99 4,732 603 172,654
Bank Stabilzation & Restoration PERC/1997/E1039 234,043 6,264 2,411 3,582 271
Restore River Embankments PERCI1997/E104O 90.072 70.574 70,574
Cutr PECI1997/E1041 n,33 n3 n3
Bank Stabilization & Restortion PERC1997/E1042 66,534 66,534 66,53
Merwn Hatchry Fix Erosion Prolems PERC/1997/E104 61.018 (33,407)(33,407)
Spelyi Hatchry Stabilze River Bank PERC/1997/E1045 40,678 40,010 40,010
No. Umpqua Eroion Repairs PERC/1997/E104 27,809 (4,396)(4,39)
Klamath Rive Doestic Water Studies PERc/1997/E1048 25,424 21,248 21,48
No. Umq Remove Contaminated Soils PERCl1997/E1052 20.339 19,875 19,875
Rogue River Doestic Water Studies PERC/1997/E1053 5,085 3,176 3,176
USTRemoval PERC/19971E054 20,33 15,553 15,55
Le Paint Removal PERc/19971E055 390,58 3,975 3,975
Annex I PERc/1997/E1056 1,325.818 628,469 3,363 625,107
Cedar Diesel PERCI19971E57 83,147 9,743 9,743
Holiday Gun Club PERc/1997/E1058 616,950 (92.325)(92,325)
Joan Substation PERc/1997/E1059 1,661,975 1,312,220 32,555 42,735 1.236,929
Montague Ranch PERC/1997/E1060 188,757 (213,459)47,23 61,686 (32,43)
Ross Island Towr Clean-up PERC/1997/E1061 101.696 (508,297)(2n.395)(230,902)
Spill Preventin. Containment and Contereasi PERCl1997/E162 2,969,252 313,537 81,00 92.93 139,597
Ashton Substation PERc/1997/E1070 28,43 25,163 25,163
Roc .springs Plant Substation PERC/19971E071 22,638 18.905 18,905
Sinclir Substation PERCl19971E072 49.326 48,330 48,33
Rocky Mountan Pow Pag 8.6.2
Idaho Genera Rate Cas . Dember 207
Environmenta Settement
PafiCor Environmental Remeiaton Co.
Spending by Environmental Proj
Cash Reai Acual Actual Remaig
Recved Cash Spein Spending Cash
Site was 199 & after at 121311206 Jan-un07 July-Dec07 at 1213112007
Parc Substation PERC/1997/El073 49,326 45,720 600 45,120
Garlnd Substatin PERCI19971E74 30,760 16,167 16,167
Dexter Substation PERC/19971E75 51,903 8,718 8,718
WyoMont Substati PERC/1997/EI76 51,903 18,198 18,198
Sal Lake Automti Sho PERC/19971E77 59,153 (70,88)(70,88)
Vern Diesl PERC/19971E078 5.593 4,185 4,185
Salt Lake Terminal Oil Spill PERC19971E079 10,170 414 414
Brer Coal Fuel Oil Spil PERC/1997/EI80 507,747 71,279 17,608 25,926 27,746
Bors Proprt PERCI19971E1 20,016 4,143 4,143
Coal Creek PERC/19971E82 3,867 2,452 2,452
Ekotek / Petm PERCl1997/El083 214.515 178,736 178,736
Envroenl Pacic PERCl1997/ElO84 10,008 8.397 8.397
Montaineer Refinery PERCI1997/EI85 102 63 63
Norwest Triangle Prpe PERC1997/EI86 10.00 9,620 9,620
Piale PERCl1997/EI87 105,061 (8,924)(8,924)
PCB,lnc.PERC1997/El088 10,007 (133,305)(133.30)
Portble Equipmnt GW PERCI1997/El089 106,84 36,88 958 365,930
Idaho Falls Pole Yard PERC/1997/El09O /05 3,761,803 1,197,989 130,325 81,788 98.876
Astora Steam Plant PERCl1997/El092 43,322 (94,586)(94.58)
Bear River Erosion Conrol PERC/19971E093 33,40 30,015 30.015
Beaver Bay Drinie Cleanup PERCI199E1094 19,693 (571)(571)
Bridger Boron Contaminated Soil Rem PERC/199E1095 199.83 197,49 197,494
Brdger Coal Warehse Spli PERCl19981E1097 146,83 144,55 144.558
Bridger Oil Spill (Ne Releases)PERCI19981E1098 280,425 (152,94)18.951 27.773 (199.672)
Cer Steam Plant PERC/19981E1099 76,423 72,89 72,89
Centralia Mine Pond Recamation PERC1998100 695,377 192.090 192,09
Cor Shore Une Repair PERC/19981E1101 38,695 8,774 8,774
Mini Central Warehouse Cleanup PERCl19981E1102 279,159 219,135 92 219.04
De Cr Ter Stablization PERCI199E1103 265,063 252,285 252.285
Dost Water System Testi and Review PERCl199E1104 180.935 120,578 612 3,211 116,755
Ha Plant Cleanp PERCl1998E1105 44,703 142,875 142.875
Hutiton As Sto Runoff Pond PERC/1998E1106 36,470 3.015 3.015
Hutington Lead Paint Removal PERCl199E1107 145.951 1,972 1.972
Le Paint Reoval (1998 Funds)PERCI199E1108 127,715 118,124 118.124
Les / Swi Reseir Ctup PERC/199109 30,58 10.042 10.042
Li Pumping Station Cleanup PERCl199E1110 19,742 19,341 19,341
Merwn Oil House Remoal PERCl199E1111 19,34 (674)(674)
Naugton South Ash Pond Recam PERCl19981E1112 245,301 5,80 5,08
Ogn Pole Treting Remediation PERCl19981E113 1,00,00 1,00,000 1.000,00
Speyai Well PERCl199E1114 10,020 9,84 9,84
Big Fork PCB So Clenup PERCI03l123 122,000 18,593 18,593
Pw Deivry UST Complanc Audit PERC12oo3lEl124 47,00 34,877 34.877
Attorey cotigency fee recived 56,00 56.00 56.000
REGULATED TOTAL 38,624,232 16.84.459 352,552 1,125.861 15,370.04
Ref'"
Rocky Mountain Power PAGE 8.7
Idaho General Rate Case. December 2007
Customer Advances for Construction
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment Rate Base:
Customer Advance 252 1 (3,272,316)CN 4.064%(132,979)
Customer Advance 252 1 (126,145)10 Sits (126,145)
Customer Advance 252 1 (177,150)OR Situs
Customer Advance 252 1 4,979,055 UT Situs
Customer Advance 252 1 3,015,392 WYE Situs
Customer Advance 252 1 1,272,631 WYW Sits
Customer Advance 252 1 (3,588,213)WY-ALL Situs
Customer Advance 252 1 (2,651)NUTIL 0.000%
Customer Advance 252 1 (54,041)CA Situs
Customer Advance 252 1 (236,015)WA Situs
Customer Advance 252 1 (1,810,548)SG 6.048%(109,501)
0 (368,625)8.7.1
Description of Adjustment:
Customer advances for constrution are booked into FERC account 252. When they are boked, the entnes do not reflect
the proper allocation. This adjustment correcs the alloction of customer advances for construction.
Rocky Mountain Power
Idaho General Rate Case. December 2007
Customer Advances for Construction
YEAR I END BASIS:
Account Booked Allocation252CN 3,272,3162521DU (49,679)2520R (926,864)252UT (11,919,134)252WYP (3,015,392)252WYU (1,272,631)
252WY-AII
252NUTIL
252CA
252WA
252SG
Total
Correct Allocation
(4,554)
(25,978)
(3,543,873)
(17,485,789)
(175,824)
(1,104,014)
(6,940,079)
(3,588,213)
(2,651)
(58,595)
(261,993)
(5,354,420)
(17,485,789)
Page 8.7.1
Adjustment
(3,272,316)
(126,145)
(1n,150)
4,979,055
3,015,392
1,272,631
(3,588,213)
(2,651)
(54,041)
(236,015)
(1,810.548)
o
Description of Adjustment:
PacifiCorp owns a 21.40% interest in the Trapper Mine, which provides coal to the Craig generating plant. The
noralized coal cost of Trapper includes all operating and maintenance costs but does not include a return on
investment. This adjustment adds the Company's porton of the Trapper Mine plant investment to rate base. This
investment is accunted for on the Company's books in Accunt 123.1 - Investment in Subsidiary Company. However,
Accunt 123 is not normally a rate base accunt. This adjustment reflects net plant rather than the actual balance in
Accunt 123 to recnize the depreciation of the investment over time.
.
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Rocky Mountain Power PAGE 8.9
Idaho General Rate Case. December 2007
Jim Bridger Mine Rate Base
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Other Tangible Propert 399 1 152,126,000 SE 6.586%10,019,723
Oter Tangible Propert 399 3 15,968,000 SE 6.586%1,051,726
168,094,000 11,071,450 8.9.1
Description of Adjustment:
PacifiCorp owns a two-thirds interest In th Bridger Coal Company (BCC), which supplies coal to the Jim Bridger
generating plant. Th Company's investment in BCC is recrded on the books of Pacific Minerals, Inc. (PMI), a whly-
own subsidiary. Because of this ownership arrangement. the coal mine investment is not incuded in Account 101 .
Elecric Plant in Service. The normalized costs for BCC provide no return on investment. The return on investment
for BCC is removed in the fuels credit which the Company has included as an offset to fuel prices leaving no return in
results. This adjustment is necessary to properly reflect the BCC plant investment in the 12-month period.
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Rocky Mountain Power PAGE 8.10
Idaho General Rate Case. December 2007
Miscellaneous Rate Base
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED Bi
Adjustment to Rate Base:
1 - Cash OWC131 1 (22,999,473)SNP 5.63%(1,295,993)2.33
2 - Fuel Stock 151 3 13,765,624 SE 6.586%906,668 8.10.1
2 - Fuel Stock 151 3 2,827,286 SSECH 6.089%172,157 8.10.1
16,592,910 1,078.824
Description of Adjustment:
1 - In order to avoid earning a rate of return on its cash balance, the company is removing the balance from rate base on
this adjustment.
2 - The cost of the company's coal plant fuel stock is increasing due to increases in the cost of coal and the number of tons
stored at each site. This adjustment reflects the increase in the fuel stock balance into results.
Page 8.10.1
Rocky Mountain Power
Idaho General Rate Case December 2007
Coal Fuel Stock Balances
Dee2007 De2008 BegndAvg Adjustment to
Plant Account Factor Balance Balance Balance Avg Balance
Bridger 151 SE 9,494,44 11.953,404 10.723.922 1.229,482
Carbn 151 SE 894,601 1.720.556 1.307.578 412,978
COOlla 151 SSECH 5.254,497 10,909,069 8.081.783 2.827,286
Colstrip 151 SE 53,305 475.097 502.701 (27,604)
Craig 151 SE 2.437,273 3,090,667 2.763.970 326,697
Hayden 151 SE 1.149,147 1.321.935 1,235.541 86.394
Hunter 151 SE 16.374.335 34.157,059 25.265,697 8,891,362
Huntington 151 SE 17.795.904 19.543,60 18,669,752 873.84
Jonston 151 SE 4.605.510 4.555.557 4.580,534 (24.977)
Naughton 151 SE 8.719.337 9.711.442 9.215.390 496.052
Deer Creek 151 SE 299.467 40.347 169,907 (129.56)
Prep Plant 151 SE 20,101,70 24.550.746 22.326,108 2.224,63
Roc Garden 151 SE 3.976,664 2.789,292 3.38.978 (593,686)
91.632,950 124.818,772 108,225.861 16,592,911
To 8.10
Rocky Mountain Power PAGE 8.11
Idaho General Rate Case. December 2007
Pro Forma Major Plant Additions
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Steam Prouction 312 3 24,938,140 SG 6.048%1,508,243
Steam Prouction 312 3 182,871,677 SSGCH 5.731%10,480,704
Hydro Prouction 332 3 15,846,934 SG.p 6.048%958,413
Hydro Production 332 3 9,591,938 SG-U 6.048%580,114
Ot Producton 343 3 630,349,967 SG 6.048%38,123,174
Transmission 355 3 81,495,574 SG 6.048%4,928,802
Distrbution - Oregon 364 3 7,335,117 OR Situs
Distribution - Utah 364 3 5,358,425 UT Situs
Distribution - Wyoming 364 3 5,785,462 WY-ALL Situs
Genral Plant 397 3 5,018,628 SO 5.755%288,847
Hydro Relicensing 302 3 42,427,815 SG-P 6.048%2,566,008
1,011,019,677 59,434,305 8.11.1
Description of Adjustment:
This adjustment places into rate base major plant additions totaling greater than $5 millon (all FERC functions) that wil be
place into service by December 2008 excluding various wind plants projected to be in placed into service Decmber 31,
2008 . The associated depreciation expense and accumulated reserve impacts are accounted for in adjustment 6.1 and 6.2.
Rocky Mountain Power Pag 8.11.1
Idaho Generl Rate Case December 2007
Malor Plant Addition Detail. Jan2008 to Dec2008
Jan08 to DecOB Plant
Projec Description Acount Factor In.Servlce Date Additions
Steam Proucion
Ch: CHLU4 CAl Environmenta Prots 312 SSGCH May-170,84.643
CHOLlJO Col Unlong&Handlin 312 SSGCH Jun 6.84.967
Ji Brr: U4 Reheater Replcement 312 SG Jun-8.850.938
Cho Un 4: TURBINE COMPONENT REPL.312 SSGCH Jun-o 5.174.067
Jii Bri U4 Cle Ai . NO 312 SG De 6,895.58
Bl U3 Exsi Devepmt 312 SG oe.Q8 9,191.622
Steam Production Total 207.809.817
Hyro ProductionCo 2 Elecal Overul 332 SG.p Jan-8.187.687
INU 4.1.1f Soda Sprs Tailr Baer 33 SG.p Jun 7.659.248
Cut 1 Overaul 332 SG-U 0e8 9,591.938
Hyro Proucton Total 25.438.872
Otr Proucton
Lake Sid Poer OUtput Impovement & Chalis 34 SG Apr.Q8/ Sept.Q8 310.551.818
Goodnoe Hils Wind Prjec (94 MW)34 SG Ju8 188.514.189
Marengo II Wind expansion (10.2 MW)34 SG Aug.Q8 131.283.960
Oter Production Total 63.349.967
Transmission
Co 11230/115 kV tronn. 250 MIA 355 SG Ma-o 5.871.271
Crr Flat. In Variable Var Devic 35 SG Ap.Q8 13.917,99
Line 1 Coerio Prjet, Cover Un 1 to 115 kV 35 SG sep-15.716,95
Glenr wi genetion 35 SG OC-o 8.232.639
Wine Countr Substion: New 230115 kV SUtation 35 SG OC-o 6.512.379
Up Gren Rir Ban prje 35 SG OC-o 12.817.194
Chapp Cri 23 Cix Energ Co 20 MW servic 355 SG oe-o 11,411,17
Lo C8nyn-. re 7 miles for 138 kV DCt 35 SG De 7.016.622
Transmission Tota 81.495.574
DItrbution
El Hom in115-12.5kV Two Fdr Sub 36 WYP Ma 5.785.462
Yew Ave 115-12.5 kV su and tap line 36 OR Ma 7.33.117
Comm Substi. Ne 138 kV Sub 36 UT Ma 5.35.425
DItrbution Total 18.479.004
GenerlCustmer IV Rent & AAR Upg 397 SO Ju 5.018.628
Genral Total 5.018.628
Intangible
U Roue RelinHy South 302 SG-P Jun 6.613,13
Yal Relinsi Suprir 302 SG-P Sep-14.28.091
Merw Reilsi Supeor 30 SG-P Sep 11.052,169
Sw Relic Supor 302 SG.p Sep-10.482.542
Intangible Tota 42427.815
1,11.019.677
Re8.11
Rocky Mountain Power PAGE 8.12
Idaho General Rate Case. December 2007
FERC 105 (PHFU)
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
RemovePHFU 105 1 (12,239.128)SG 6.048%(740,215)
RemovePHFU 105 1 (953.014)SE 6.586%(62.770)
RemovePHFU 105 1 (505.024)UT Situs
(13,697.166)(802,985)8.12.1
Description of Adjustment:
This adjustment removes all Plant Held for Future Use (PHFU) assets from FERC accunt 105. The Company's is making
this adjustment in compliance with Title 16 of Public Utilty Regulation. chapter 5. -Powers and Duties of Public Utilties
Commission" secon 61-502A.
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ROCky Mountain Power
RESULTS OF OPERATIONS
Page 9.1
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAHO
DECEMBER 2007
FILE:
PREPARED BY:
OATE:
TIME:
JAM 10 De7 GRC
Revenue Requirement Dertent9~
1:26:17 PM
TYE OF RATE BASE:
ALLOCATION METOD:
Yea-En
ROLLED-IN
FERC JURISDICTION:Seprate Juicn
80R 12CP:12 Coental Peaks
DEMAND %
ENERGY %
75% Demand
25% Ener
TAX INFORMATION
TAX RATE ASSUMPTIONS:
FEDERAL RATE
STATE EFFECTIVE RATE
TAX GROSS UP FACTOR
FEDERAUSTATE COMBINED RATE
TAX RATE
35.0010
4.54%
1.614
37.951%
CAPITAL STRUCTURE INFORMATION
CAPITAL
STRUCTURE
EMBEDDED~WEIGHTED
COST
DEBT
PREFERRED
COMMON
49.20%
0.40%
50.40%
100.00%
6.20
5.41%
10.75%
3.050
0.022%
5.418%
8.90%
OTHER INFORMATION
t
ROLLED.IN Page 9.2
Year.End
RESULTS OF OPERATIONS SUMMARY
UNADJUSTED RESULTS IDAHO
Decrption of Account Summary:Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJTOTAL
1 Oping Reve
2 Genel Busiss Revenues 2.3 3.228.941.107 3,04.741.273 184.199.833 16.79.728 201.179.561
3 Intertmental 2.3 0 0 0 0 0
4 Speial Sats 2.3 856.88.831 805,576,184 51,288.667 84.356.311 135.84.978
5 Ot Op Reven 2.4 156,475.22 149.453,853 7.021.568 1.630.45 8.52.027
6 Tota Opera Revenues 2.4 4.242.281.360 3.99.771.291 242.510,069 102.96.497 345,476.566
7
8 Openg Expses:
9 Stem Prouen 2.5 85,983.104 80,118,372 54.864.733 2,09.769 56.955.502
10 Nucar Pron 2.6 0 0 0 0 0
11 H) Pro 2.7 34.359.368 32,281,33 2.078.033 64.759 2,142.792
12 Otr Powr Supl 2.9 1,199,378.442 1.128,29.248 71.088.195 96.876,48 167.96,659
13 Tramissn 2.10 154.194,872 144.859,554 9.33.318 901.06 10.2.38
14 D1lrbutln 2.12 221,34.872 210.697.578 10.64,29 71,86 10.721.182
15 Custer Accting 2.12 95.457.786 91.184,36 4,273.420 57,3 4.3.758
16 Custoer Service & Infor 2.13 48.969.452 43.100,792 3.86.66 (2,05.139)1,815.521
17 Sal 2.13 0 0 0 0 0
18 Adminste & Genera 2.14 180.356.471 170.818.274 9.538.197 636.857 10,175.054
19
20 Tot 0 & M Expenses 2.14 2.787,040.368 2.621,350,518 165,68,85 98,651,979 264,341,828
21
22 Deiatin 2.16 417.781.814 393,942,713 23.839.041 (962.683)22,876.35
23 Amortti 2.17 64,157.451 61,093,80 3,06.845 157,357 3,221.201
24 Tax Oter Than Inme 2.17 101,472,747 96,96,335 4,50.412 80,750 5,118.163
25 Ine Taxes. Federa 2.20 150.692.971 143,542.906 7,150,071 (3.451.416)3,69,655
26 Ince Taxes. State 2.20 24,326.973 23,182.070 1,144,903 (266.807)878,09
27 In Taxes. Def Net 2.19 78,94,590 75,927.65 3,017.933 2.566.44 5,58,379
28 Invstment Tax Creit Adj.2.17 (5.854.86)(5.147.769)(707.091)488,647 (218.44)
29 Mi Revenue & Exse 2.4 (11.343,723)(10.609.502)(734.221)493.180 (241.041)
30
31 Tot Oprating Exses 2.20 3.607.219,337 3.40.245,594 20.973.743 98.285.451 30.2,194
32
33 Op Revue fo Ret 635.062.023 599.525.697 35.536.326 4.881.046 40.217.372
34
35 Rate Ba:
36 EIe Pl in Se 2.30 16.347.947.992 15.40.837.138 94.110,853 71.192,357 1.013,30.211
37 Plant He fo Fut Use 2.31 13,697,167 12,894,182 802,985 (802.985)0
38 Mise Defe Debi 2.33 133.178,754 129.185.979 3,992,716 45,303 4.03,079
39 Ele Plnt Ac Adj 2.31 71,825.613 67.481,84 4,343.968 0 4.3,968
40 Nucar Fuel 2.31 0 0 0 0 0
41 Prepaents 2.32 39.29,959 37.00.708 2,29,251 0 2.29,251
42 FuelStok 2.32 96.239,038 89.90,289 6.33,749 1,183,137 7,521.886
43 Matl & Sulis 2.32 149,717,022 140,727,152 9,04,870 0 9,049.870
44 Working Capil 2.33 74.042.035 70,136,989 3,90,046 (152,781)3.752,26
45 Weatin Loans 2.31 10.890,479 5.298,042 5.592.437 0 5.592,437
46 MiUaus Rate Ba 2.34 5,149,186 4,768.058 381,128 0 381.128
47
48 Totl EIe Plat 16,942,04,244 15,96,23,181 978,814.063 71.46.031 1,050,279.09
49
50 Rate Base Deduens:
51 Acm PIOV For Depr 2.38 (6,184,58.183)(5.814.581.669)(36.982.514)(1.596,768)(371.579.282)
52 Acem PIv For Amor 2.39 (402.210.256)(38.60.40)(21,803.856)(38,851)(21,642.507)
53 Acum Deflnce Taxes 2.35 (1,329.490,178)(1.247.326,119)(82184,059)(66,251)(82.83,310)
54 Unaored ITC 2.35 (10,543.126)(10,490.911)(52,215)(104,123)(156,338)
55 Customer Adv for Const 2.34 (17.485.789)(17,35.757)(131,031)(36,625)(49,656)
56 Custmer Servic Deposits 2.34 0 0 0 0 0
57 Mise. Rate Base Deductons 2.34 (59.165.685)(55.855.431)(3.310,254)(3.808.871)(7.119.125)
58
59 Totl Rate Bas Deduons (8.003,459.216)(7.526.215.287)(471,243.929)(6,58.289)(48,87.218)
80
61 Tot Ra Base 8.938.585.028 8,437.014.894 501.570.134 64.881.742 56,451.876
62
63 Ret on Rate Bas 7.105%7.08%7.100%
64
65 Ret on Equi 8.001%7.962%7.992%
66 Net Powr Costs 94,860.037 62,642,437 68,039.94
67 100 Bas Poits in Equ
68 Revenue Reqrement Impact 72.604.665 4.074,06 4,601,069
69 Rate Ba De (592,089.468)(33,310,160)(37,545,56)
ROED-N Page 9.3
V_End
FERC BUS UNADJUSTED RESULTS IDAO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADJUSTMENT ADJTOTAL
70 sale to Uhmate Customers
71 44 Resideti sale
72 0 S 1.263.790.934 1.214.263.337 49.527.597 8.006.554 57.53.151
73
74 81 1.26.790.934 1.214,26.337 49,527.597 8,006.554 57.534,151
75
76 442 Commercial & instal sales
77 0 5 1.928.738,024 1,79.30,878 134.429.145 8.777.711 143.20856
78 P SE
79 PT SG
80
81
82 81 1.928.738.024 1.794.308.878 134,429.145 8.777.711 143.206.56
83
84 44 Publi 5lr & Hiy Lighting
85 0 S 18.902.690 18.65.599 243,091 195,46 43.55
86 0 50
87 81 18.902.690 18.659.599 243.091 195.463 438.54
88
89 44 Ot sales to Pubc Authrity
90 0 5 17,509.459 17.50,45
91
92 81 17.509.459 17.509.459
93
94 44 Intrdental
95 DPW 5
96 GP 50
97 81
96
99 Totl sale. to UltilMe Cusomers 81 3,28,941.101 3,04,741,273 184,199,833 18,979.728 201,179,561
100
101
102
103 447 sales fo Resalen NPC
104 W5F S 7,616.288 7.616.288
105 7.616.288 7.616.288
106
107 447NPC Sa fo RestePC
108 W5F 5G 882.810,22 810,68.375 52.185.855 63,459.124 135.64.978
109 W5F 5E (13.621.686)(12.724.49)(891.187)897,187
110 W5F 5G
111 84.248.543 797.959.876 51.288.667 84.356.311 135.644.978
112
113 Tota sale for Resae 81 856,864.831 805,576.164 51.288.667 84.356.311 135.644.918
114
115 44 Prvion fo Rat Refund
116 W5F 5 3 3
117 W5F SG
118
119
120 81 3 3
121
122 Totl Sae. fr Eleriit 81 4,085.805.940 3,850,317.44 235.488.500 101,336,039 336,824.539
123 4S Forfed Disnts & Interest
124 CU5T S 6.784,670 6,416.032 368.639 368.639
125 CU5T SO
126 81 6.784.670 6,416.032 368.639 368.39
127
128 451 Mise El Revene
129 CU5T 5 7.20.337 7.06,014 142.323 142.323
130 GP SG
131 GP 50 10.908 10.280 629 629
132 81 7.215.245 1.012.294 142.951 142,951
133
134 45 Wetesales
135 P SG 107.48 100.979 6.500 6,00
136 81 107,480 100.979 6,00 6,SOO
137
138 45 Re of Ele Prort
139 DP 5 12.80.490 12,473.816 335.675 33.675
140 T 5G 5.274.077 4,95.104 318.973 318.973
141 GP SO 677.192 638.166 39.026 135.584 174.60
142 81 18.760.759 18.067.086 693.673 135.584 829.257
143
144
ROLEo-N Page 9.4
Yea-End
FERC BUS UNADUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTENT ADTOTAL
145
146 456 oir Ele Revenue
147 OMSC S 28.947.692 28.946,13 1.679 1.679
146 CUST CN
149 OTHSE SE 15.573.966 14.54.195 1.025.n4 61.176 1.086.949
150 OTHSO SO 244.061 229.99 14.06 14.065
151 OTHSR SG 78.841.54 74.073.256 4.768.288 1.433.699 6.21.987
152
153
154 B1 123.607.265 117.797.460 5.809.805 1,494.875 7.3õ.680
155
156 Tot Oter Elecrl Revenues B1 156.475,419 149,453,851 7.021,568 1,630,458 8,652,027
157
158 Totl Elec Opeting Revenues B1 4,42.281,360 3,99,771.291 24,510,069 102,966.497 34476,566
159
160 Summa of Reveues by Fact
161 S 3.292.30.586 3.107.255,43 185.048,148 16.979.728 202,027.876
162 CN
163 SE 1,952.282 1.823,96 128,58 958.363 1.08.94
184 SO 932.162 878.44 53,719 135.584 169.303
165 SG 947,093.330 889.813.715 57,279.615 84.892.823 142,172.43
166 DGP
167
168 Total Elec Op Revenues a.242.281.360 3.999.71.291 2a2.510.069 102.966.497 345.476.566
169 Misus Revenus
170 41160 Gain on Sa of Utilty Plant. CR
171 DP S
172 T SG
173 G SO
174 T SG
175 P SG
176 B1
177
178 41170 Loss on Sa of Ut Plant
179 OPW S
180 T SG
181 B1
182
183 4118 Gan fr Emsin AHowanes
184 P S
185 P SE
f4.663,498!
~ 13.697 .692)(965.806)758,103 (207.703)
186 B1 14.663.98 13.697.692)(965.806)758.103 (207.703)
187
188 41181 Gain frm DIpositn of NOX Credit
169 P se
190 B1
191
192 4194 Impat Hous Intrest Incme
193 P SG
194 B1
195
196 421 (Gain) I Loss on Sat of Uttity Plant
197 DP S (706,221)(706.221)
198 T SG
199 T SG
20 PTD CN
201 PTO SO 4.175,984 3,935.327 240.65 (228.531)12,125
202 P SG (149.988)(140.917)(9.071)(36.392)(45.463)
203 B1 3.319.775 3.088.190 231.585 (264.923)(33.338)
204
205 Totl Miscellaneous Revenues 11,34,723)10,609.502)34,221 493,180
206 MlscUaneous Expenses
207 4311 Inrest on Custoer Deposits
20 CUST S
20 81
210 Totl Miscellaneous Expenses
211
212 Net Mise Revenue and Expense B1 10,609.502)34,221)493,180 241.041)
213
ROLED-N Pag 9.5
V..r-nd
FERC BUS UNADUSTED RESULTS IDAHO
ACCT oeSCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
214 500 Opn Supervisin & Engineering
215 P SNPPS 20.195.720 18.974.29 1,221,425 12,303 1,33,728
216 P SNPPS 1.310.396 1.231.144 79,252 79,252
217 82 21,506.117 20,205.44 1.300.677 12,303 1.312,980
218
219 501 Fue ReI NPC
22 P se 12.819,982 11,975,599 84,383 610 84.993
221 P se
222 P se
22 P se
224 P se 1,762.999 1.64,880 116.119 116.119
22 B2 14.582.982 13.622,479 96.503 610 961,113
228
227 501NP Fuel RePC
22 P se 516.191,53 482.192,770 33,99.767 2,119.38 36,117,805
22 P se
23 P se
231 P se
23 P se 50.403.877 47.084,044 3.319.833 3.319,833
233 82 566.595.413 529.276.814 37.318.600 2.119.038 39.437.638
23423 Tota Ful Relte 581,178.395 542.899.292 38.279.102 2.119.648 40.398.751
236
237 502 Steam Expenses23P SNPPS 31.714.301 29.796.240 1.918.61 13,908 1,931.969
239 P SNPPS 2.053,090 1.928.920 124.170 124.170
240 82 33.767,391 31.725.160 2.042,231 13.908 2.056.139
241
242 503 Stam Fro OIer Sourcs-Non-NPC
243 P se
244 82
245
248 503NPC St Fro Otr Sours-PC
247 P se 4.84.079 4.525.96 319.119 (85,191)233.929
248 82 4.84.079 4,525.960 319.119 (85.191)233.929
24925 50 EI Ex
251 P SNPPS 2,687.282 2,524.757 162.525 1.261 163,787
252 P SNPPS 1,320.614 1.240.744 79.870 79,870
253 82 4,007.896 3.765.501 242.395 1.261 243.656
25425 50 Mi. St Exnse
256 P SNPPS 40,241.240 37,807,474 2,43,765 (2.593)2,431.172
257 P se
258 P SNPPS 1.603.350 1,50.380 96.970 96.970
259 82 41.844.590 39.313.855 2.530,735 (2.593)2.528.142
26
261 507 Ren
262 P SNPPS 743,038 698.09 44.93 44,938
263 P SNPPS 116.165 109.140 7,026 7.026
264 82 859.203 807.239 51.964 51.96
26
266 510 Ma Supesion & Engineering
267 P SNPPS 4.413.141 4.146.237 26,904 (5.325)261.579
26 P SNPPS 1.786.866 1,678.798 108.069 108,069
269 82 6.20,007 5.825.035 374.973 (5,325)369.648
270
271
272
273 511 Matenanc of Strres
274 P SNPPS 21.651.22 20,341.957 1.309.46 5.407 1.314.872
275 P SNPPS 862.871 81o.85 52.186 52,186
276 B2 22.514.293 21,152.642 1.361.650 5,407 1.367,058
2n
278 512 Maintenace of Boier Plant
279 P SNPPS 90,472.54 85.000,820 5.471.723 21.290 5.493,013
26 P SNPPS 3.997.568 3.755,798 241.770 241.770
261 B2 94,470.112 88.756.618 5.713,494 21.290 5.734.784
282
283 513 Maintenan of eiec Plant
284 P SNPPS 31.041,437 29,164,070 1.877.367 8.1n 1.88.544
285 P SNPPS 797.219 749.004 48,215 48.215
28 82 31,838.656 29.913.074 1,925.582 8.177 1,933.760
287
288 514 Maintean of Misc. Steam Plant
28 P SNPPS 9,395,338 8.827,114 56,224 1,881 570.105
290 P SNPPS 2,556.29 2.401,442 154,587 154.587
291 B2 11.951.367 11.228.556 722.811 1.881 724.692
2929 Totl Steam Power Geion B2 854983.104 800,118,372 54,864,733 2,090,769 56,955,502
ROLLEo-N Page 9.6
Year.End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADJTOTAL
29 517 Opraion Super & Engnering
295 P SNPPN
29 82
29729 518 Nucar Fuel Exnse
29 P SE
30
301 B2
302
303 519 Colants and Water
304 P SNPPN
30 B2
30
307 520 Stea Exnse
308 P SNPPN
309 B2
310
311
312
313 523 Ele Exses
314 P SNPPN
315 B2
316
317 524 MIse NucJ Exnss
318 P SNPPN
319 B2
320
321 528 Matena Supe & Engneering
322 P SNPPN
323 82
324
325 52 Mana of Stres
326 P SNPPN
327 82
328
329 53 Maintenance of React Plant
33 P SNPPN
331 82
332
333 531 Maitenc of Ele Plant
334 P SNPPN
335 B2
336
337 532 Maintena of Mise Nuer
338 P SNPPN
339 82
34
341 Totl Nuclear Power Geneion B2
34234 535 Operan Sup & Engeri
344 P DGP
34 P SNPPH 4.922,053 4.624.370 297.683 5.939 303.622
34 P SNPPH 3.50.43 3.29.371 212.067 212,067
34734 B2 8.428.491 7,918.742 509.750 5.939 515.689
349
350 536 Wate For Pow
351 P DGP
352 P SNPPH 146,55 137.692 8.86 32 8.895
35 P SNPPH 70.232 65.984 4.248 4,248
354
355 82 216.788 203.677 13,111 32 13.143
356
ROLLO-IN Page 9.7
Vear-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
357 537 Hydraulic Expenses
35 P DGP
359 P SNPPH 4.29.292 4.039.274 26.019 470 260.48
36 P SNPPH 406.674 382.078 24.595 24.595
361
36Z 82 4.705.96 4.421.352 284.614 470 285.84
3636 53 Ele Exnses
36 P DGP
366 P SNPPH
367 P SNPPH
36
369 82
370
371 53 Misc. Hy Exs
372 P DG
3n P SNPPH 8.29.62 8.107.715 521.915 55.788 577.702
374 P SNPPH 6.07.896 6.114.303 393.594 393.594
375
376
377 82 15.137.525 14.222.017 915.508 55.788 971.296
378
379 54 Ren (Hy Genertin)
36 P DGP
361 P SNPPH 34.192 32.125 2.06 (5)2,062
38 P SNPPH 11,233 10.554 679 679
3638 82 45,426 42.678 2.747 (5)2.742
385
386 541 Mai Supervio & Engering
387 P DGP
38 P SNPPH
389 P SNPPH
390
391 B2
392
393 54 Manc of Str
394 P DGP
395 P SNPPH 89.136 841.939 54.198 226 54.424
396 P SNPPH 124.785 117.238 7.547 7.547
39739 82 1.020.921 959.176 61.745 226 61.971
3940
401
402
403 54 Main of Das & Wateys
404 P DGP
405 P SNPPH 73.036 685.884 44.152 923 45.075
40 P SNPH 287,859 270.45 17.410 17,410
407
408 B2 1.017.895 956.333 61.562 923 62.485
40
410 544 Maince of Ele Plant
411 P DGP
412 P SNPPH 1.129.866 1.061.533 68.334 972 69.30
413 P SNPH 548.628 515.44 33.181 33.181
414
415 82 1.678,495 1.576.980 101.514 972 102.486
416
417 54 Manc of Misc. Hyro Plant
418 P DGP
419 P SNPH 1,33.44 1.249.976 80.46 415 80.879
420 P SNH m.420 730.402 47.018 47.018
42142 82 2.107.86 1.980.378 127.482 415 127.897
423
424 Totl Hydraulic Poer Generion B2 34.359.368 32.281.335 2.078.033 64.759 2,142.792
ROLLED-N Pag9.S
V_End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
425
426 54 Opon Sup & Engineg
427 P SNPPO 729.753 685.618 44.135 (1)44.134
428 P SNPPO
429 82 729.753 685,618 44.135 (1)44.134
43
431 547 Fuel-NonPC
432 P SE
43 P SE
43 82
4343 547NPC FueNP
437 P SE 261,141.972 243,941,952 17.20.020 14.531.135 31.731.155
43 P SE 64,695.537 60,43.389 4.261.148 4.261.148
439 82 325,837.509 30.376.341 21,461.168 14.531,135 35.992.303
44
441 54 Getln Exnse
442 P SNPPO 11,819,36 11.104.538 714,828 (481.228)233.600
44 P SNPPO 10.636.272 9.992.997 64.275 64.275
44 82 22.45.63 21.097.535 1.358.103 (481.228)876.875
4444 549 Mieo Oler
447 P SNPPO 5.931.46 5.572.735 358.731 1,168.027 1,52.758
44 P SNPO
449 82 5.931.46 5.572.735 35,731 1,16a.27 1.526,758
450
451
4524545 550 Re
45 P SNPP 98,99 927.303 59.693 (376.447)(316.754)
45 P SNPPO 10.977.690 10,313.766 66.924 66.924
457 82 11.964.686 11.241,069 723,17 (376.447)347.170
4545 551 Ma Supsio & Enee
46 P SNPPO
461 82
462
463 552 Maen of Strus
484 P SNPO 339.85 319,30 20.554 (5.49)15.059
465 P SNPPO 276,119 259.420 16.700 16.700
46 82 615.974 578.720 37,254 (5.495)31.758
46746 553 Maint of Geneon & Electr Plant46PSNPPO 3,359,178 3.156,017 203.161 111.577 314,738
470 P SNPPO 1.271.491 1,194,592 76,899 76,899
471 B2 4.630.669 4,350.609 280.060 111,577 391.37
472
473 55 Mainan of Mi. Ot
474 P SNPPO 113,44 106,587 6.861 (8.182)(1.321)
475 P SNPPO 282.634 28.541 17.094 17.094
476 B2 396.83 372.128 23,955 (8.182)15,773
477
478 Tot Other Power Geeration 82 372,561.778 34274.755 24,287,023 14,939.385 39,226.408
479
48
481 555 Purc Por-Nn NPC
482 DMSC S 5.366.023
483
5.368.023
484
485 55C Purse Pow-NPC
486 P SG 633.103,690 59.813.973 38.289.717 74,86.54 113.173,260
487 P SE 153,134.779 143.048,613 10,08.166 (4,44.94)5,645.221
46 Sesol Co P SG
489 DGP
490 786.238.469 737,862.585 48.375.883 70,442.598 118.818.481
491
492 Tota Purced Pow B2 763.738.961 720,731,100 43.007.860 75,810.621 118.818,481
493
494 55 Syste Contrl & Loa Dispatch
495 P SG 2.535.081 2,381.760 153.320 881 154.201
496
497 82 2.535.081 2.381,760 153.320 881 154.201
49849
ROLLED-IN Page 9.9
Yeand
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
50
501 557 Otr Expe
502 P S (183.792)(150.819)(32.973)6,570.000 6.537.026
503 P SG 59.521.272 55,921.46 3,599.810 (44.422)3.155.387
504 P SGT 1.122.425 1.054.273 68,152 68.152
50 P SE
50 P SG 82,718 77,716 5,003 5.003
507 P TROJP
5050 B2 60.542.623 56.902.632 3.639.991 6.125.577 9.765,569
510
511 Embede Cot Difftils
512 Compan Ow Hy P DGP
513 Copay Ow Hy P SG
514 Mi Contct P Me
515 Ml.c Contrct P SG
516 existing OF Contra P S
517 existig OF Conra P SG
518
519
520
521 Tot Other Pow Supply B2 826.816,664 780,015,493 46,801,172 81,937.079 128,738,251
52252 Totl Prouction Expense 82 2,088.720,914 1,96,689.954 128,030.961 99.031,992 227,062,953
524
525
526 Summar of Proion Expense by Facor
527 S (22,68.300)(17,282,304)(5.40.996)11.938.023 6.537,026
52 SG 69,242.761 853.194.912 42047.850 74.44.002 116,487.851
529 SE 1,06,99,761 994,85.205 70.145.55 12,124.647 82.270.203
53 SNPPH 34,359,3 32,281.335 2,078.033 64.759 2,142,792
531 TROJP
532 SGCT 1,122.425 1,054.273 68.152 68.152
533 DGP
53 OEU
535 OEP
53 SNPPS 268.959.631 252,693.120 16.26.511 56.311 16,322.22
537 SNPPO 46,724.269 43,89.414 2.825.855 40.25 3,234.105
53 DGU
539 Me54SSGCT
541 SSECT
542 SSGC
54 SSGC
54 SSECH ....
545 Tot Proon Ex by Facr B2 2.088.720.914 1.96.689.954 128.030.961 99.031.992 227.062.953
54 56 Op Survisin & Engineeri
547 T SNPT 8,207,35 7,710,975 49,375 141.782 63.157
5454 B2 8.207.350 7.710.975 496.375 141.782 63.157
55
551 561 Lo Dlpa
552 T SNPT 7,888,745 7.411.63 477.106 12.814 489.920
553
554 B2 7.888.745 7.411.838 477.106 12.814 489.920
55 56 St Ex55T SNPT 1,006.28 94.184 60.844 319 61,163
55755 B2 1.006.028 94,184 60.844 319 61.163
55956 56 Ov line Expense
561 T SNT 125,807 118.199 7,60 14 7,622
56256 B2 125.807 118.199 7.609 14 7,622
56
565 56 Un lin Ex
568 T SNPT
58758 B2
56
ROLLED.IN Page 9.10
Yea-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
570 565 Trasmissn of Elecit by Othrs
571 T SG
572 T SE
573
574
575 565NC Transmissn of Elecity by QtPC
576 T SG 104.789.310 98,451.718 6.337.592 856,270 7,193,8
577 T SE 1.802.800 1.684.059 118.741 (110.032)8.709
578 106.592.110 100.135.777 6.456.333 746.239 7.202.572
579
580 Tota Transmissin of Electrity by Oters 82 106.592.110 100.135.777 6.45.333 746.239 7,202.572
581
582 566 Misc. Transission Exnse
58 T SN 2.751.80 2.585.377 166.427 (5.842)180.58
584
585 B2 2.751.80 2.58.377 166,427 (5.842)160.586
586
587 567 Rents. Trasmission
588 T SNPT 1.35,267 1,274,241 82.026 129 82.155
58959 82 1,356.267 1.274.241 82.026 129 82.155
591
592 568 Malnt Supervsin & Engineenng
593 T SNPT 56.234 52,83 3.401 20 3.421
59459 82 56.234 52.83 3.401 20 3.21
596
597 569 Maintenanc of Strres
598 T SNPT 3,233.567 3,038.003 195.56 1.551 197.115
59960 B2 3.233.567 3.038.003 195.564 1.551 197.115
601
802 570 Maince of Station Equipen
603 T SNPT 9.272.54 8.711.747 56.79 4,413 56,210
604
805 82 9,272.545 8,711.747 56,798 4,413 565.210
80
807 571 Maintean of Overad Lines
608 T SNPT 13.323.841 12,518,024 80,818 (433)80.38
80
610 82 13.323.841 12.518.024 805.818 (433)805.385
611
612 572 Maintenc of Unrground Uns
613 T SNPT (0)(0)
614
615 82 (0)(0)
616
617 573 Maint of Mis. Transmissio Plant
618 T SNPT 38,572 357.555 23.017 57 23.074
619
620 82 38,572 357.555 23,017 57 23.074
621
622 Totl Transmissio Expese B2 154,194,872 144.859,554 9.335,318 901,062 10,26.380
623
624 Summary of Trasmission Expese by Facor
625 SE 1,802.800 1,68.059 118,741 (110.32)8.70
626 SG 104.789.310 98,451,718 6.337.592 856,270 7.193.86
627 SNPT 47.602,762 44,723.776 2.878.985 154.823 3,33.809
628 Tota Transmission Expese by Factor 154.194.872 144.859.554 9.335.318 901,02 10.236.380
629 56 Operatin Supervsion & Enginering
63 DPW S 197.509 236.002 (38.492)11 (38,481)
631 DPW SNP 19.530.509 18.616.001 914,508 (2.278)912.231
632 82 19,728.019 18.852.002 876.016 (2.266)873,750
63
634 581 Loa Distcing
63 DPW S
636 DPW SNPD 12,681.549 12.088.677 592.872 30.324 623.196
637 82 12.661.549 12.068.677 592.872 30.324 623.196
638
639 582 Statin Exnse
64 DPW S 3.361.261 3,187,322 173.939 1,2 175.
641 DP SNPD 14.696 14,008 68 8 69
642 B2 3,375.957 3.201,330 174.627 1.273 175.900
64
ROLLEDoN Page 9.11
Year-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
64 58 Ovrhad Un Exnses
64 DPW S 6.910.600 6.802.998 161.601 1.80 169.401
64 DP SNPD 642.038 611.915 30.063 262 30.325
641 82 1.612.638 1.414.914 191.664 2.061 199.726
648
649 58 Undrgrond Line Exnse
65 DPW S 23.53 23.535
651 OPW SNPD
652 B2 230.535 230.535
65365 58 Stret Ligng & Signa Systems
65 DP S
65 DP SNPD 248.162 236.542 11.620 20 11.820
657 82 248.162 23.542 11.620 200 11.820
65
659 586 Meter Exses
66 DPW S 4.625.918 4.360.921 26.99 2.812 281.802
661 DP SNPD 1.169.50 1.114.139 54.161 552 55.313
662 82 5.195.18 5.15.666 319.152 3.364 323.115
66
664 587 Customer Insllation Expenses
665 DP S 9.331.55 8.102.201 635.356 6.851 64.20
66 DP SNPD
661 B2 9.331.558 8.102.201 635.356 6.851 642.208
66
669 58 Misc. Distron Exnses
670 OPW S 2.142.20 2.53.001 201.20 1.316 20.520
671 DPW SNPD 6.35.655 6.059.001 297.64 8.554 306.201
612 82 9.098.860 8.594.008 504.852 9.869 514.121
673
674 589 Ren
615 DP S 3.921.526 3.812.49 49.029 38 49.068
616 OPW SNPD 36.405 351.155 11.250 11.250
617 82 4.289.931 4.223.651 66.280 38 66.318
618
679 590 Mat Suplsio & Engineri
680 DPW S 543.016 520.148 22.928 240 23.168
681 DPW SNPD 5.959.341 5.68.291 219.04 8.989 28a.33
682 82 6.502.411 6.200.446 301.912 9.229 311.201
683
684 591 Manten of Strres
685 DPW S 1.248.681 1.158.681 90.00 90.00
68 DP SND 134.105 127.826 6.219 6,219
687 82 1.382.192 1.286.507 96.285 96.285
68
689 592 Mananc of St Equipment
69 OPW S 9.915.46 9.621.68 353.715 3.119 358.953
691 DP SNPD 1.768.399 1.685.594 82.805 12.619 95.424
692 82 11.143.862 11.301.282 43.519 15.198 452.311
693 593 Mainen of Overhad Lines
694 DPW S 89.826.662 84.865.111 4.961.551 24.425 4,98.915
69 OP SNPD 1.68.189 1.601.515 78.674 1.120 19.794
69 82 91.506.851 86.466.626 5.40.225 25.545 5.65.169
69169 594 Maintenan of Unrgrond Lines69OPWS 22112.112 22.023.121 148.990 5.11 154.710
100 DPW SNP 28.951 21.595 1.35 12 1.361
101 B2 22.801.663 22.051.311 150.346 5.191 156.131
702
103 595 Maina of Une Trasfrmers
104 DPW S 60.688 60.688
705 DP SNPD 684.216 652.235 32.041 261 32.302
706 82 144.964 112.923 32.041 261 32.302
701
108 596 Ma of St Ligg & Sigal Sys.10 DPW S 4.335.96 4.110,152 165.812 1.60 161.412
110 DPW SNPD
111 B2 4.33.964 4.110.152 165.812 1.66 161,412
112
ROLLED-IN Pae 9.12
Vear-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
713 597 Mainte of Meters
714 OPW S 3.956.99 3.672.402 284.598 3.067 287.66
715 OPW SNPD 1.519.486 1.44.337 71.149 713 71.862
716 82 5,476.485 5.120.738 355.747 3.780 359.527
717
718 59 Maint of Mis Distrition Plant
719 OPW S 3.487.765 3.44.38 39.384 136 39.520
720 DP SNPD 979.48 93.621 45.864 (36.046)9.818
721 82 4.467.250 4.382.001 65.248 (35.910)49.339
72
723 Total Distribution Expense 82 221.340.872 210.697.578 10.64.29 17.869 10.721.162
724
725
726 Summar of Ditrn Exnse by Facr
727 S 167.595.125 159.46.455 8.126.671 52.579 8.179.249
728 SNPO 53.745.747 51.22.124 2.516.623 25,2 2.541.913
72
730 Tota Ditrbutin Ex by Fac 221.340.87 210.697.578 10.643.294 77.869 10.721.162
731
732 901 Supervion
733 CUST S 262.967 252.277 10.689 115 10,05
734 CUST CN 2.49.732 2.392.393 101.339 772 102.111
735 82 2.756.699 2.644.670 112.029 887 112,16
736
737 902 Mete Reag Expens
738 CUST S 27.323.838 25.747.110 1.576.728 15.98 1.59.714
739 CUST CN 84.132 80.829 34.303 279 34.583
740 82 28.167.970 26.556.939 1.611.031 16.266 1.627.297
741
742 903 Customer Reipts & CoIçts
743 CUST S 6,19.019 6.191.137 227.882 2,395 23,27
744 CUST CN 49.188.818 47.189.905 1.99.914 5.192 2.00.105
745 82 55.607.837 53.381.042 2.226.795 7.587 2.34.382
746
747 90 Unc Accts
748 CUST S 9.36.54 9.022.016 341.528 341.528
749 P SG
750 CUST CN (812.507)(779.489)(33.018)32.510 (50)
751 82 8.551.037 8.242.527 308.~10 32.510 341.020
752
753 905 MI. Cutoer Accunts Expense
754 CUST S 3.768 3.768
755 CUST CN 370,476 355,420 15.55 88 15.143
756 82 374.243 359.188 15.055 88 15.143
757
758 Tot Custome Accots Expense 82 95.457.786 91.184.366 4,23.420 57.338 4,330.758
759
760 Sumar of Custme Ac Ex by Facr
761 S 43.373.135 41.216.30 2.156.827 18.497 2.175.324
162 CN 52.084.65 49.96.057 2.116.593 38.841 2.155.43
763 SG ...
764 Tota Customer Acunts Exnse by Facor 95.457.786 91.184.366 4.273.420 57.338 4.330.758
765
766 907 Supsio
767 CUST S
768 CUST CN 423.544 406.332 17.212 161 17.373
769 B2 423.544 40.332 17.212 161 17.373
170
171 908 Cumer Asisnc
772 CUST S 38.718.172 35.171,471 3.54.701 (2.04.33)1.503.36
773 CUST CN 4.038.065 3.873.968 164.097 1.49 165.592
774
775
776 82 42.756.237 39.045.439 3.710.798 (2.041.840)1.668.958
777
ROLED-N Pag 9.13
Vear-Ed
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
778 909 Infnnatlonal & Instctional Adv
779 CUST S 629.957 618.25 11,705 (8.280)3,424
780 CUST CN 3.154.588 3,026.394 128.195 (3.180)125.015
781 82 3,784.546 3.64.646 139.899 (11.46)128.39
782
783 910 MI. Customer Service
784 CUST S 2.00 1,376 624 624
785 CUST CN 3.126 2,99 127 127
786
787 82 5.126 4.375 751 751
788
789 T~I Cuæomer Senrce Ex~se 82 46.969,452 43.100,792 3,868,660 (2,053,139)1,815,521
79
791
792 Sumar of Cusmer Se Ex by Facor
793 S 39,35.128 35.791.099 3.559.029 (2.051.615)1.51,14
794 CN 7.619.324 7,3.693 309.631 (1,524)30.107
795
796 Tota Cuer Se Exse by Fact 82 46,969.452 43.100.792 3.868,660 (2.M3.139)1.815,521
797
798
799 911 Supeision80 eUST S
801 CUST eN
802 B2
803
804 912 Demontrtin & Seng Expnse
805 eUST S
80 CUT CN
807 82
8080 913 Ader Exns
810 eUST 5
811 CUT CN
812 82
813
814 918 Misc. Sas Expens
815 eUST 5
816 eU5T CN
817 82
818
819 T~I Sale. Expense 82
820
821
822 Tota Saes Exse by Factr
823 5
824 CN
825 Tot Sa Expe by Fac
826
827 Tot Custom Service Exp Including Sale.B2 46,969.452 43,100,792 3,86,660 (2.053,139)1.815,521
828 92 Admintie & Genra Salas
829 PTD 5 351.79 351.79
83 eUST CN
831 PTD 50 82,94.771 78.169,484 4.780.287 (189,459)4.590.828
832 82 83.301,566 78,521,279 4,780.287 (189.459)4.590.828
83
834 921 0f 5uppies & expses
835 PTO 5 (937.48)(938.909)1.425 (1.26)161
836 eU5T eN
837 PTO 50 12.717.213 11,984.336 732.876 (18.610)714.266
83 82 11.779.729 11.045.427 734.302 (19.875)714,427
83984 922 A&G Exns Transfed
841 PTO 5
842 CU5T CN
843 PTO SO 12.697.805)(19.505.017)(1,192.787)36,732 (1.156.055)
84 82 (20.697,805)(19,505.017)(1.192.787)36,732 (1.156,055)
84
ROLLEI)N Pag 9.14
Yea-End
FERC BUS UNAUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
84 923 Outside Servces
847 PTD 5 40.783 40,783
84 CUST CN
84 PTD 50 9.759.436 9.197.12 562,424 (12.713)549.711
85 B2 9.80.219 9.237.795 562,424 (12.713)549.711
851
852 924 pro Inurance85PTO SO 24.516.013 23.103.187 1,412,826 1,12.826
854 B2 24.516.013 23.103.187 1.412.826 1,412.826
8585 92 Injs & Damages
857 PTO 50 11.291,287 10.64.585 65.702 (147,301)503,401
858 B2 11.291.287 10,640.585 650,702 (147.301)503,401
85
860 926 Emplyee Pensions & Benefi
861 LABOR 5
862 CUST CN
863 LABOR 50
864 B2
86586 927 Franc Reqirments
867 OMSC 5
868 DMC 50
869 B2
870
871 928 Regtory Commissin Exe
872 DM5C 5 8.068.821 7.780.05 328,76 32.764
873 CU5T CN
874 DMSC 50 407 38 23 23
875 FERC 5G 1.922.411 1,80,145 116.266 (142.341)(36.075)
876 B2 10.011.639 9.566.585 44.054 (142.341)302.713
877
878 929 Duple Chares
879 LABOR 5
880 LABOR 50
t845.34O)
(5,50.481 )(336.859)(486)(337.348)
881 B2 (5.508.481 )(33.859)(486)(337.346)5.84.34)
8888 93 MI Ge Expenses
884 PTD 5 12.190.297 12.189.673 624 171.988 172.612
88 CU5T CN 5.724 5,491 233 233
886 LAOR 50 13.372.148 12.801.528 770.619 96,380 1.736.999
887 82 25.568.169 24.796.693 771.76 1,138.368 1,90.844
888
889 931 Rent
890 PTD 5 902.697 902.697
891 PTO SO 5.38.807 5,079.20 310.60 (29,087)261.521
892 82 6.292.504 5,981.897 310.608 (29.087)281.521
893
894 93 Mainnc of Genel Plt
895 G 5 42,149 42, 149
896 CU5T CN
897 G 50 24.29.341 22.896.174 1.40.166 3,018 1.403.184
898 B2 24.338.489 22,938.323 1,400.166 3,018 1.403.184
899
900 Total Administrative & Generl Expense B2 180.356.471 170.818.274 9,538,197 636.857 10,175.054
901
902 5ummar of A&G Exse by Fact905 20.679.057 20.3.243 33.814 170.724 501,538
904 SO 157.749,278 148,658.394 9.090.885 608,474 9.699.359
90 SG 1.922,411 1,80,145 116.26 (142,1)(26.075)
90 CN 5,724 5,491 233 233
907 Total A&G Expese by Fact 180,356.471 170.818.274 9.53.197 636.857 10.17.054
90890 Tot O&M Expense B2 2;787.040,368 2,621,350,518 165.689,85õ 98.651.979 26,341.828
ROLLED-IN Page 9.15
Vur-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADJTOTAL
910 40P Steam Deprtin
911 P SG 37.507.935 35.23,478 2.268.457 2.2,457
912 P SG 40,33.873 37.896,38 2.439,48 2,439,48
913 P SG 60.60.591 56.941.142 3,66.44 (2.592.649)1.072.800
914 P 50 9.113.517 8.562.337 551.160 551.180
915 B3 147.563.915 138.39,342 8.924.574 (2,592.649)6.331.925
916
917 40P Nu Deiation
918 p SG
919 B3
92
921 403HP Hy Deiatin92P SG 4.979,312 4.678.168 301.146 301.146
923 P SG 1.187.40 1.115.587 71.813 71.813
924 P SG 5,276.56 4.957.44 319.124 136.53 45659
92 P SG 1.477.963 1.38,577 89.386 89.386
92 83 12.921.243 12.139.774 781.469 136.535 918.04
927
928 400P Ot Proucn Depration
92 P 50 39.783 37.377 2,40 2,406
93 P SG 29,2.267 27.50.415 1.770,852 1.876.846 3.647,698
931 P SG 3.161.554 2.970.346 191.20 191.20
93 P SG
933 B3 32.481.604 30.517.137 1.96.467 1.876.846 3.841.313
9393 403TP Trassion Deati93T 50 12.270,765 11,528.637 742.128 742.128
937 T SG 13.361,64 12,55.542 808.104 80,104
938 T SG 31.736.237 29.818.728 1,919.509 5.943 1.925.452
939 B3 57.370,648 53.90.907 3,469.741 5.943 3,475.684
94
941
94294 403 Dlbuon Depratn9436.. &.. RI DPW S 274.805 257.336 17.469 17.489
94 361 au DPW S 93.033 918.35 14.678 14.678
94 362 _~DPW S 14.029.40 13.65.65 374.754 374.754
947 363 -.-,iiDP S 142,101 142,101
94 38 Po" T_ DPW S 34.35.246 32,283,44 2.06.80 (237.774)1.831.32
94 36 OH Co DPW S 16.53.64 15.648,682 881,962 881.962
95 366 UGCo DP S 6,473,439 6,319,003 154.43 154.436
951 367 UGe-DPW S 13,788.826 13,327.754 461.073 461,073
95 36 LlT..DP S 23.342.420 21,974.708 1,367.712 1.367.712
95 369 s.DPW S 9.972.44 9,43,963 53.480 533.480
95 370 ~DPW S 8,71.780 6.014.80 45,974 45.974
95 371 .Mleu_DP S 379.042 371,772 7,27 7.270
95 372 "-"'DPW S 1.29 1,166 127 127
957 373 _LJ DPW S 2.373.614 2,341.318 32.29 32.29
95 83 129.065.095 122.694.059 6,371,036 (237.774)6.133,262
95996 40GP Ge Depriation
961 G-ITUS S 12.940.217 12,073.436 86,760 (89,186)777594
962 PT SG 48.20 44.832 28,377 28.377
963 PT SG 807.216 758.396 48.82 48.820
96 P SE 37,803 35.126 2.477 (39)2.438
965 CUST CN 1,38.927 1,328.647 56.280 (2,825)53.455
96 G-SG 4.911.245 4.614.216 297.029 (29,197)267.832
967 PTD SO 17.841.227 16.624.586 1,016.641 (30,33)986.305
96 G-G 50 16.958 15.933 1.026 1.026
96 G-G SG 170,708 160.384 10.324 10.324
970 83 38.379.310 36.051.555 2.327.754 (151.584)2.176.170
971
972 403GVO Gen Vehis
973 G-G SG
974 B3
975
976 403MP Miin Deprciatin
977 P SE
978 83
979
ROLLED-N Pag 9.16
Ve.,-End
FERC BUS UNADJUSTD RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
98 40P Experimenta Plant Deprciation
981 P SG
982 P SG
98 B3
98 4031 ARO Deiation
985 P S
986 83
987
98
989 Totl Depriaton Expense B3 417.781.814 393.942.773 23.839.041 (962,683)22,876.358
99
991 Summary S 142.005.312 134.767,495 7.237,817 (326.961)6,10.56
99 DGP
993 OGU
99 SG 256.712.746 241,186.919 15.525.827 (602.522)14.92.30
995 SO 17.641.227 16.624,58 1,016.41 (30.33)98,30
99 CN 1.384,927 1.328,647 56.280 (2.825)53.455
997 SE 37.603 35.126 2,4n (39)2.43
99 SSGCH99SSGCT -----
100 Tota Deprciati Expese By Factor 417.781.814 39.942.773 23.839.041 (962.683)M.876.358
1001
1002 404GP Amor of L T Plat - Capl Lease Gen
1003 I-ITUS S 967.674 967.674
1004 I-SG SG
1005 PTO SO 1.708.800 1.610.324 98.476 98,476
1008 P SG
1007 CUST CN 232,427 222.982 9.44 9.44
1008 P SG
1009 54 2.90.901 2.80.980 107.921 107.921
1010
1011 044SP Amo of L T Plant - Ca Lease Steam
1012 P SG
1013 P SG
1014 54
1015
1016 4041P Am of L T Plant. Inta Plant
1017 1-SITUS S 38,191 17.79 20.401 20.401
1018 P SE 3.711 3,466 244 244
1019 I-G SG 6.479,693 6.087.805 391.888 222.107 613.995
1020 PTO SO 28,791.417 27.132,205 1.659,212 (7.147)1,52.06
1021 CUST CN 4.849.670 4.652,591 197,079 197.079
1022 1-5 SG 2.057,084 1.932,673 124,411 124,411
1023 I-SG SG 30.688 29,95 18,730 18.730
1024 P SG
1025 1-5 SG
1026 I-G SG 5.777 5.428 34 349
1027 P SG 17.88 16.802 1.082 1.082
1028 54 42.553.115 40.139.719 2,413.396 214.960 2.628.355
1029
1030 404MP Amor of L T Plnt - Mln Plant
1031 P SE
1032 54
1033
1034 400P Amor of L T Plant. Otr Plant
1035 P SG 293.921 276.145 17.776 (10.421)7.355
1036 54 293.921 276.145 17.776 (10.21)7.355
1037
1038
1039 40HP Amorttin of Oter Electrc Plant
1040 P SG 2.284 2.146 138 138
1041 P SG 38.242 35,929 2.313 2.313
1042 P SG
104 54 40.526 38,075 2,451 2.451
1044104 Totl Amortizaon of LImited Tenn Plant 54 45796,464 43.254,920 2,541.54 204.539 2.746.083
1046
1047
1048 405 Amortllon of Oter Electr Plant
1049 GP S
1050
1051 54
1052
ROLLED"N Page 9.17
Yea-End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
1053 40 Amrton of Plant Acqisiton Adj
1054 P S
1055 P SG
105 P SG
1057 P SG 5,479.353 5.147.96 331.38 331.388
105 P SO
1059 B4 5,479.353 5.147.965 331.388 331.388
106 407 Am of Prp Loss$. Unr Plant. etc
1061 OPW S 9,752.248 9.752.248
1062 GP SO
106 P SG 780.128 732.94 47.182 47.182
106 P SE
106 P SG 33,105 312.959 20.146 (47.182)(27.036)
106 P TROJP 2.016.153 1.892.568 123,585 123.58
1067 B4 12.881.634 12.690.721 190.913 (47,182)143.731
106
1069 Tot Amrtization Expense B4 64 157,451 61.093.606 3.063.845 157,357 3,21.201
1070
1071
1072
1073 Sumary of Amoza Expense by Factor
1074 S 10,758,114 10.737.713 20.401 20,401
1075 SE 3.711 3,46 244 244
1076 TROJP 2,016,153 1.892.56 123.585 123585
10n DGP
1078 OGU
1079 SO 30.50.217 28.742,529 1.757.688 (7.147)1.75,54
1080 SSGCT
1061 SSGCH
1082 CN 5.082.097 4.875.573 20.524 20.524
1083 SG 15,797.159 14.841.756 955.402 184.504 1,119.907
106 Total Amortzatl Expese by Facor 64.157.451 61.093.66 3,063.845 157.357 3.221.201
1085 40 Taxs Oter Than Incoe
108 OMSC S 23.301,27 23.301.297
1087 GP GPS 69.102,426 65.120.144 3.982.282 60.750 . 4.591.033
1088 GP SO 8.523.359 8,32.169 491,190 491.190
1089 P SE 54.664 50.724 35.94 35.94
109 P SG
1091 OMSC OPRV-lD
1092 GP EXCTAX
109 GP SG
109
109
109
1097 Totl Taxes Oter Tha Incme B5 101,472,74 96.963.335 4;509,412 608.750 5.11.163
1098
1099
1100 41140 Derr Instent Tax Crit - Fed
1101 PTO DGU (5.85.86)(5.147,769)(707.091)48.647 (218.44)
1102
1103 87 (5.854.860)(5.147.769)(707.091)488.647 (218.44)
1104
1105 41141 De Invstment Tax Credi -Idaho
1106 PTO DGU
1107
1108 87
1109
1110 Totl Deferr ITe B7 (5,854.860)(5, 147,769)(707.091)488.647 (218.445)
1111
ROLLED-N
Page 9.18
y...end
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1112
1113 427 Intrest on Lo Tem Debt
1114 GP S 3.374.156 3.374.156
1115 GP SNP 278.731,910 263.011.521 15.720.389 15.720.389
1116 B6 278.731.910 263.011.521 15.720.389 3,374.156 19.94.546
1117
1118 428 Amorttion of Debt Disc & Exp
1119 GP SNP 7.664,485 7.232.211 432.274 432.274
1120 B6 7.664.485 7.232.211 432.274 432.274
1121
1122 429 Amortin of Premium on Debt
1123 GP SNP
158.884)l55.563J
(3.321)(3,321)
1124 B6 58.884)55,563 13,321)(3.321)
1125
1126 431 Otr . Intere Exnse
1127 NUT OTH
1128 GP SO
1129 GP SNP 29.764.583 28.08.870 1,678.713 1,78,713
1130 B6 29.764,583 2s.85.870 1.678.713 1.678.713
1131
1132 432 AFUDC . Bo
1133 GP SNP (28.53.980)
l27.037.905)
(1.616,075)(1,616.075)
1134 128.653.980)11.616.075)(1.616.075)27.037.905)
1135
1138 Total Elec. Inrest Deuctns for Tax B6 287.44.113 271.236.133 16,211.981 3.374.156 19.586.137
1137
1138 Nolty Portn of Interest
1139 427 NUTIL NUTIL
1140 428 NUTIL NUIL
1141 429 NUTIL NUTi
1142 431 NUTIL NUTIL
1143
1144 Total No Inst
1145
1146 Tota Intest Dectns fo Tax B6 287.44.113 271.236.133 16.211.981 3.374.156 19.586.137
1147
1148
1149 419 Inter & Dides
1150 GP S
1151 GP SNP 140.90.06)138.98.972)12.307.089)12.307.089)
1152 Tot Opti Dens for Tax B6 40.906.060)38.598.972)2.301.089)2.301.089)
1153
1154
1155 41010 Defe Incme Tax. FedR
1156 GP S 359.730.458 34.857.399 13.873,59 (70.029)13.167.030
1157 P TROJ 14,65 13.758 901 901
1158 PT DGP 2.438 2.438
1159 LABOR SO 37.617.391 35.44.55 2.167,841 (27.061)1.88.780
1160 GP SNP 21,316 20.114 1.202 1.202
1161 P SE 7,127,36 6.657,927 469.441 (5,423)46.018
1162 PT SG 7,66,825 7.20.019 46.80 (466,27)(2.222)
1163 GP GPS 1.001 94 58 58
1164 D1TEX D1TEX 2,373.505 2.373.50
1165 CUST SADDEBT 1,887,38 1.819,266 68.09 68,094
1166 CUST CN 23.817 22.849 96 96
1167 P IBT 121.199 115.49 5.70 8.774 14.478
1168 DPW SNPD
1169 B7 414,215.852 397.164.778 17,51.074 917.739 17.968.813
1170
ROLLED-IN
Page 9.19
Vea,-End
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUMC FACTOR Ref TOTAL OTHER IOAH ADUSTMENT ADTOTAL
1171
1172
1173 41110 Deferr Incme Tax. Fedl-R
1174 GP 5 (29,98.77)(279,583.593)(11,405,178)248.600 (11,156,578)
1175 P SE (7,43,238)(6.94,84)(48.390)7,144 (482,246)
1176 PT OGP (300,173)(30,173)
1177 GP SNP (1.765.373)(1,66,807)(99,566)(99.56)
1178 PT SG (11.033,42)(10.36,126)(667,294)248,904 (418,391)
1179 GP GPS (531.55)(50,925)(30.63)(30,633)
1180 LABOR SO (22,243.997)(20.962.105)(1.281,892)298.51 (983.D2)
1181 PT SNPD (38,879)(37.059)(1,820)(1,820)
1182 CUST CN
1183 P SGCT (35.221)(33.592)(21,62)(21.629)
1184 DlTEX DITEX 84,208 84,208
1185 P TROJD (581.632)(54,895)(35.737)(35.737)
1166 P SG
1187
1188
1189 87 (335,270.262)(321.237,122)(14.033.141 )1.64.707 (12.384,433)
1190
1191 TOhI Deferr Income Taxe.B7 78.945,590 75,927,656 3.017.933 2,56.44 5,584,379
1192 SCHMF Adition - Flow Through
1193 SCHF 5
1194 SCHMAF SNP
1195 SCHMF SO
1196 SCHMF SE
1197 SCHM TROJP
1198 SCHMAF SG
1199 B6
120
1201 SC Adds. Peanent
1202 P 5
1203 P SE 87,039 81.306 5,733 5.733
120 LABOR SNP 1,096.54 1,034.699 61,84 61.84
120 SCHMAP-50 SO 11.167.890 10,524,29 64,591 64.591
120 SCHMAP SG 119,015 111,817 7.196 7.198
1207 DP SADDEBT
1208 B6 12,470.488 11,752.121 718.366 718.366
1209
1210 scT Ad . Tempoiy
1211 SCHMT-5ITUS 5 29.272.039 28,462,675 80.36 (1,249.326)(439,962)
1212 P SG
1213 DP CIAC 65.63,740 62,585.232 3.073,508 3.073.508
1214 SCHMT-5NP SNP 60.771,286 57,34,805 3,427.481 3,427.481
1215 P TROD 1,532,58 1,43,421 94.165 94,165
1216 P SG
1217 SCHMT-5E SE 19.578.509 18.288.978 1,289,531 166.211 1,45,743
1218 P SG 28,819,66 27.076,66 1,742.995 (505,528)1,237,467
1219 SCHT-GPS GPS 1.40.64 1,319,928 80.717 80.717
122 SCMAT-50 SO 15,680.298 14.776.66 903.635 (26.367)877.268
1221 SCAT-5NP SNPD 29.370,967 27,995.683 1.375,2 1.375.284
122 CUST CN
122 P SG 938.63 881.86 56.768 56,768
1224 BOKDEPR SCHMDEX 495.661.101 467.378.191 28.282.910 (64.885)27.634.026
1225 B6 748,664.466 707.528.107 41.136.358 (2.263.894 )38.872.464
122
1227 TOTAL SCHEDULE. M ADDTINS 86 761,134.953 719.280.228 41.854.725 (2.263.894 )39.590.831
1228
ROLLED-IN Page 9.20
Year-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
1229 SCHMDF Dedio - Flo Through
1230 SCHMOF S
1231 SCHMDF DGP
1232 SCHMDF DGU
1233 B6
1234 SCHMDP Deucons - Pennanent
123 SCHMDP S
1236 P SE 4.39,479 4,105,973 289,507 28.507
1237 PTD SNP 381.06 359.571 21.492 21.492
1238 SCHMP IBT
1239 P SG 10,90,49 10.241,23 65,255 (659,25)(0)
1240 SCHMOP-50 SO 25,05.142 23.606.535 1.44.607 1.44.607
1241 B6 40.727,178 38,313.317 2,413.860 (659.255)1.754.605
1242
1243 SCHMOT De - Temporary
1244 GP S 68,145,601 66,295.851 1.849.750 (2,470.570)(62o.2O)
1245 DPW BADDEBT 4.973.203 4,793,777 179,426 179,426
1246 SCHMDT-5P SNP 62.812,29 59,29,701 3.542.593 3.542.59
1247 SCHMDT CN 62.756 60.206 2.55 2,55
1246 SCHMOT TROJD 38.625 38.252 2.373 2,373
1249 CUST DGP 6,423 6.42
1250 P SE 22.946.826 21.43.441 1.511.384 114.901 1.626,265
1251 SCHMDT-5G SG 12.022,379 11,29.273 727.106 (878.222)(151.116)
1252 SCHMDT-GPS GPS 66.940.561 63.082.86 3.857,697 (190.021)3,687.676
1253 SCHDT-50 SO 60.098,279 56,63,894 3,46,38 (57,331)3.40.054
125 TAXEPR TAXEPR 604.113.141 569,144,970 34.96,171 7,569,532 42.537.703
1255 DPW SNPD
1256 B6 902,160.088 852.055.652 50.104.436 4,08.289 54.192.725
1257
125 TOTAL SCHEDULE - M DEDUCTIONS B6 942.887.266 890.36.970 52.518.297 3.29.034 55.947.330
1259126 TOTAL SCHEDULE - M ADJUSTMENTS B6 (181.752,313)(171,088.741)(10.663,572)(5,692,928)(16,356.500)
1261
1262
1263
126 4011 St in Taxes
1265 IBT I8T 24,326.973 23.182,070 1.144,903 (29.232)915.71
1266 I8T SE (3,(2)(3,06)
1267 REC P SG (34.513)(34,513)
1268 I8T I8T ---
1269 Tot State Tax Expese 24,326,973 23.182,070 1,144.903 (266,807)878,06
1270
1271
1272 Cation of Taxab Incme:
1273 Operang Revenues 4.242.281.36 3,99.771,291 242.510.069 102.96.497 34.476.566
1274 Operating Deuctns:
1275 o & M Expenss 2.787.04,388 2,621,35.518 185.689.850 98,851.79 26,341,828
1276 Deprtin Exnse 417,781,814 393,942,773 23.839,041 (962,683)22,876,3
1277 Amotin Expense 64,157.451 61,09,60 3.06.845 157.357 3.221.201
1278 Taxes Oter Than Ince 101,472.747 96,96.335 4.50.412 60.750 5.118,163
127 Intest & Divinds (AFUDe-Equil)(40.90.060)(38.59.972)(2.307.089)(2.307.089)
128 Mise Revenue & Expense (11.34.723)(10.609.502)(734.221)493.180 (241,041)
1281 Total Operati Deducions 3,318.202.597 3,124.141.758 194.060.839 98.94.582 29.00.421
1282 Ot Deuctions:
1283 Interet Dectns 287,44.113 271.236.133 16,211.981 3.374.156 19.58.137
1284 Intst on PCRBS
1285 Scheule M Adjustments (181.752.313)(171,088,741)(10,66.572)(5.692.928)(16.358,00)
1286
1287 Incme Befo State Taxes 454.878,336 43,304.659 21.573.678 (5.04.168) .16.524.509
1288
1289 State Incme Taxes 24.326.973 23.182.070 1,144.903 (26.807)878.096
129
1291 Tota Taxable Income 43.551.36 410.122.589 20.428.775 (4,782.361 )15.646.414
1292
1293 Tax Rate 35.0%35.0%35.0%35.0%35.0%
129
129 Fedral Income Tax. calclated 150.692,977 143.54,90 7.150.071 (1.673.826)5.478.245
129
1297 Adjustments to Calculated Tax:
1298 40910 PMI P SE
1299 4010 REC P SG (1.777,59)(1.717.59)
130 40910 P SO
1301 40910 __LAOR S
1302 Federal Income Tax Expense 150.692.977 1 .542.906 , 71 3.4 1,4 6). 98. 55
1303130 Totl Opeating Expenses 3,607.219,337 3.400,245.594 206.973.743 98.285,451 305,259.194
ROLLED-N Page 9.21
Vear-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADJTOTAL
130 310 Lan and Lan Rights
130 P SG 2,329.517 2.188.630 140.88 140.88
1307 P SG 34.798.44 32,693.857 2,104.588 2.104.58
1308 P SG 52,841,353 49.645.541 3,195.812 3,195.812
130 P S
1310 P SG 1.246.363 1.170.984 75.379 75.379
1311 B8 91.215,679 85.699.011 5.516.667 5.516.667
1312
1313 311 Stur and Imprvements
1314 P SG 23,06,00 22.84.363 14.216.84 14.216.84
1315 P SG 328.521.96 308.65.160 19.868,804 19.86.804
1316 P SG 188.828,179 175.528.927 11.29.252 (176,928)11.122.324
1317 P SG 53.032.033 49.824.689 3.207.34 3.207.344
1318 B8 803,48.185 754.85.138 48.592.046 (176.928)48.415.119
1319
1320 312 Bor Pl Equipment
1321 P SG 730.217.780 88.054.663 44.163.117 44.163.117
1322 P SG 667.820.168 627.43D.2O 40.389,34 40.38.348
1323 P SG 1,216.540.716 1,142.965.090 73.575.625 12,58,208 86.143.834
1324 P SG 227.303.718 213.556.530 13.747,187 13.747.187
1325 B8 2,841.882.382 2.670.007.104 171.875,278 12.568.208 184.443.486
1326
1327 314 Turblor Unit
1328 P SG 147.50.469 138.583.491 8.920.979 8.920.979
132 P SG 145.269.412 136.48.608 8,785.804 8.785.80
133 P SG 407.154.283 382.529.845 24,624.43 24.624.43
1331 P SG 54,788.625 51.475.043 3.313,582 3.313.582
1332 B8 754.716.789 709,071.988 45.64,802 45.644.802
1333
133 315 Acssor Elecri Equipment
1335 P SG 88,157,59 82.825.375 5.331.684 5.331,84
133 P SG 139,35,575 130.930.255 8.428.320 8.428.320
1337 P SG 68,125.707 64.005.507 4,120.200 4.120.200
1338 P SG 46.965.801 44.144.129 2,841,672 2.841,72
1339 B8 342.627,142 321.905.266 20.721.876 20.721.876
134
1341
1342
134 316 MIse Po Plant Equipment
134 P SG 4.918.591 4.621.118 297.473 297,473
134 P SG 5.327,245 5.005.56 322.188 322.188
134 P SG 12.510.930 11.754.276 756.65 756.65
1347 P SG 3,144.722 2.95.531 190.191 190.191
.134 B8 25,901.487 24.334.981 1.566.506 1.56.506
1349
135 317 Steam Plant ARO
1351 P S
1352 B8
135
135 SP Unassi Steam Plant- Accunt 30
135 P SG 526.307 494.476 31.831 31.831
135 B8 526.307 494,476 31.831 31.831
1357
135
1359 Tot Stem Prouction Plant B8 4.860.317.970 4.56.368.964 29,949.006 12.391.281 306.340,287
1360
1361
1382 Summar of Steam Prouction Plant by Factr
136 S
136 DGP
1365 DGU
136 SG 4.86.317.970 4.56.36.964 293,949.00 12.391.281 306.40.287
1367 SSGCH .-.-
136 Total Steam Prouctn Plant by Facor 4,860.317,970 4.566.368.964 29.949.006 12.391.281 306.340.287
1369 320 Land and Land Rihts
1370 P SG
1371 P SG
1372 B8
1373
1374 321 Stures and Improvements
1315 P SG
1376 P SG B8
1377
ROLLED-IN Pae 9.22
V....nd
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1378
1379 322 Reaor Pla Equent
138 P SG
1381 P SG
1382 B8
1383
138 323 Turbenetor Un
138 P SG
1386 P SG
1387 B8
1388
1389 324 La an Land RIts
1390 P SG
1391 P SG
1392 B8
1393
1394 325 MI. Powr Plat Equpment
1395 P SG
1396 P SG
1397 B8
1398
1399
140 NP Unssd Nuclear Plat. Acc 30
1401 P SG
1402 B8
1403
140140 Totl Nuclear Proucion Plant B8
140
1407140
1409 Sumar of Nucear Pron Plnt by Facr
1410 OGP
1411 OGU
1412 SG
1413
1414 Tot Nur Pla by Facto
1415
1416 330 Lan and Land Rights
1417 P SG 10.626.875 9.84.169 642.707 642.707
1418 P SG 5.307.562 4.98.56 320.99 320.99
1419 P SG 3.122.410 2.93.569 188.841 188.841
1420 P SG 63.700 597.253 38.447 38.447
1421 B8 19.692.547 18.501.554 1.190.993 1.190.993
1422
1423 331 Sln and Imprmen
1424 P SG 21.461.160 20.163.203 1,27.958 1.297.958
1425 P SG 5.327.119 5.00.938 322.181 322.181
1426 P SG 50.016.734 46.991.753 3,24.981 3,24.981
1427 P SG 7.101.54 6.672.047 429.497 429.497
1428 B8 83.906.557 78.831.941 5,74.616 5,74.616
1429
143 332 Resir. Das & Wateiwys
1431 P SG 151.64.543 .142.473.175 9.171.368 9.171.368
1432 P SG 20.315.731 19.087.04 1.228.683 1.228.683
143 P SG 74.756.625 70.235.391 4.521.234 1.538.527 6,59.761
1434 P SG 33.2.922 31.254.960 2.011.963 2.011.963
1435 B8 279.983.821 263.050.574 16.933.247 1.538.527 18.71.774
143
1437 33 Wate Whl. Turbs. & Generator
143 P SG 32.833.723 30.847.96 1.985.763 1.98.763
1439 P SG 9.479.349 8.906,44 573.305 573.305
144 P SG 35.531.537 33.382.612 2.146.925 2.146.925
1441 P SG 12.699.370 11.931.320 788.050 768.050
1442 B8 90.54.979 85.067,936 5.476.044 5.476.044
144144 334 Acssory EIc Equipment
144 P SG 5.102,415 4.793.824 308.591 308.591
144 P SG 3.968.930 3.72.891 240.038 240.038
1447 P SG 30.647.338 28.793.806 1.85.532 1.85.532
144 P SG 3.423.222 3.216.188 207,034 207.034
1449 B8 43.141.905 40.532.709 2.609.196 2,609.196
145
ROLLED-N Page 9.23
Vea,.end
FERC BUS UNADJUSTeD RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
1451
1452
145 33 Misc. Por Plant Equipment
145 P sa 1.371.505 1.288.55 82.94 82.94
1455 P sa 197,88 185.917 11,96 11.96
145 P sa 982.272 922,865 59.407 59,407
1457 P sa 12,96 12.179 784 784
145 B8 2.564.625 2.409.518 155.107 155.107
145
146 33 Roas, Railads & Bries
1461 P sa 4.63,94 4,356.505 280.44 280.44
1462 P sa 828,976 778.840 50,136 50.136
146 P sa 7.882,825 7.40,077 476.748 476,748
146 P sa 592.158 55.345 35.813 35.813
1465 B8 13.940.904 13.097.767 843.137 843.137
1466
1467 337 H)ro Plat ARO146P S
146 B8
1470
1471 HP Unssif H)ro Pl - Ace 300
1472 P S
1473 P sa
1474 P sa
1475 P sa
1476 B8
1477
1478 Totl Hyraulic Prouction Plant B8 533,714.338 501.491,998 32,282,340 1,538,527 33.820.867
1479
148 SUmary of Hyul Plant by Fiir
1481 S
1482 sa 533.714.33 501.491.998 32,282,34 1.53,527 33,820.867
1483 DGP
148 DGU -.-
148 Tolal Hy Plant by Facr 533,774.338 501.491.998 32.282.340 1.538.527 33.820.867
1486
1487 34 La an Lan Ri
148 P sa 21.542.670 20,239,783 1,302.887 1,302.887
1489 P sa
149 P SG
1491 B8 21.542.670 20.239.783 1.302.887 1.302.887
149
1493 341 St an Imprments
149 P SG 108.044.808 101,510.325 6,53.483 6,534,483
1495 P SG 170.926 180.588 10,337 10.337
1496 P SG 4,237.997 3,981.686 256.311 25.311
1497 B8 112.45.730 105.52.599 6,801.132 6.801.132
1498
149 342 Fue Hoers. Prouc & Acsses
1500 P SG 6.597.356 6,198.352 399.004 399.004
1501 P SG 121.339 114.000 7,339 7.339
1502 P SG 2,257.625 2.121.085 136.54 136.540
1503 B8 8.976.320 8.433,438 542.882 542.882
150150 34 Pre Movers
1506 P S
1507 P SG 714.173 727.351 46.821 46.821
1508 P SG 839,146,070 .788.395,38 50.751,032 38.059.004 88.810.036
150 P SG 51,39.802 48,291.174 3.108.628 3.108.628
1510 B8 891.320.45 837.413.563 53.906.82 38.59.004 91.965.485
1511
1512 34 Ge
1513 P S
1514 P SG
1515 P SG 207,48.517 194.935.982 12,54,534 12,548.534
1516 P SG 15,873.643 14.913.615 96.028 960.028
1517 B8 223.35.160 209.849.598 13.508.563 13.508.563
ROlI-ED-IN Pa 9.24
Vear-End
FERC BUS UNADJUSTED RESUI- TS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAl-OTHER IDAH ADJUSTMENT ADJTOTAI-
1518
1519 345 Accsso Elec Plnt
1520 P SG 112.64.196 105.831.545 6.812.651 6.812.651
1521 P SG 156.586 147,116 9,470 9,470
1522 P SG 3.072.971 2,667,120 185.851 185.851
1523 B8 115.873,754 108.865.781 7,07,973 7,007.973
1524
1525
152
1527 34 Misc. Powe Plant Equipmt
1528 P SG 6.653,73 6.25,699 402.374 402,374
1529 P SG 11.813 11,099 714 714
153 B8 6.66.886 6,261.798 403.088 403.088
1531
153 347 Ot Proucti ARO
1533 P S
1534 B8
1535
1536 OP Uncssifd Oter Pro Plat-Acc 300
1537 P S
153 P SG
153
154
1541 Total Other Production Plant B8 1.380.189.56 1,29.716.558 83,473.006 38.059.004 121,532.010
1542
154 Summary of Oter Pructin Plant by Facto
154 S
154 DGU
154 SG 1,38.189.564 1,29.716.558 83.473.006 38.059.004 121.52,010
1547 SSGCT -...-
154 Tota of Oter Prucon Plant by Facr 1.38.189,564 1.296.716.558 83.473.006 38.09,004 121.32.010
1549
155 Expeenta Plant
1551 103 Experimental Plant
1552 P SG
1553 Tot Experimental Proucton Plant B8
1554
1555 Total Prouction Plant B8 6,n4.281.873 6,364.577,521 409,704.352 51.988.812 461.693.164
155 35 La an Land Rights
1557 T SG 21,25.197 19.922.720 1.282,477 1.282,471
155 T SG 48.627.811 45.68.831 2.94.98 2,94,980
155 T SG 23.515.907 22,093,680 1,422.227 (63.234)1.58.994
156 B8 93.348.915 87.703.231 5,645.684 (63.234)5.582,451
1561
1562 352 Strtures an Imprvement
1563 T S
156 T SG 7,679.83 7.215.359 46,471 46.471
1565 T SG 18.276.825 17.171.45 1,105.371 1.105.371
1566 T SG 37.781.428 35.49.431 2,284.997 2.28.997
1567 B8 63.73a.84 59,883.244 3.854.840 3.54,840
156
156 353 Sta Equipmen
1570 T SG 134,220.44 126,102,876 8.117.569 6.117.569
1571 T SG 195.n9.604 183.938.975 11,84.629 11.84.629
1572 T SG 69.655.578 654.522.282 42.133.29 42.133.296
1573 B8 1,026.65.627 96.564,133 62.091.493 62.091,493
1574
1575 354 Towers and Fixts
1576 T SG 156.34.058 146.884.709 9.45.349 9.455.349
1577 T SG 126.99.44 119,312.959 7.68.484 7.68.484
1578 T SG 141.302.906 132.756.994 8.545,912 8.54.912
1579 B8 424.636.408 398.954.662 25.681,746 25.681,746
1580
1581 355 Pos and Fixtres
1582 T SG 68.63.597 64.485,498 4.151.09 4.151.09
158 T SG 118.39.485 111.233.121 7.160,36 7.160.364
158 T SG 341.601.204 320.941.376 20.659.828 4.928.802 25.588.30
1585 B8 528.631.286 49.659.995 31.971.291 4.928.802 36.900.093
158
ROllED.IN Page 9.25
Vear-End
FERC BUS UNADSTD RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1587 35 Clering and Graing
158 T SG 207,525,185 194.974,191 12,55.994 12.55.994
1589 T SG 158.557,353 148,967,903 9.589.450 9,589.450
159 T SG 33,381.58 310,400.311 19.981.273 19.981.273
1591 B8 696.464,121 65,342.404 42.121.717 42.121.717
1592
1593 357 Und Conit
1594 T SG 6.371 5,86 385 38
1595 T SG 162.746 152.90 9.84 9.84
159 T S.G 3.108.495 2,92,495 188.000 188.000
1597 B8 3,277.612 3.79.384 198.228 198.228
159
1599 35 Unro Conduc
160 T SG
1601 T SG 1,018.66 957,055 61.60 61.608
1602 T SG 6.34.850 5,962,99 383.854 38.854
1603 B8 7,365.512 6,920.51 44.462 44.462
1604
160 359 Ro an Tra
160 T SG 1.89,428 1.776,96 114.332 114,332
1607 T SG 494.754 46.832 29,922 29.922
160 T SG 9,087,04 8.537.466 54.579 549.579
160 B8 11,472,227 10,778.394 693.833 693.33
1610
1811 TP Unil Trans Plant. Ac 300
1612 T SG 21.93.847 20.604.48 1.326.364 1.32.364
1613 B8 21,930.847 20,604.483 1.326.364 1.326.364
1614
1615 T50 Unssed Trans Sub Plant. Acct 300
1616 T SG
1617 B8
1618
1619 Totl Transmission Plant B8 2,877,520,64 2.703,489,982 174,030,658 4,865,568 178,896,225
1620 Summary of Trasmision Plat by Facr
1621 DG
1622 DGU
1623 SG 2,877.520.640 2.703,489.982 174,030.658 4,865,568 178.896.225
1624 Tota Trasmisn Plant by Fact 2.877 .520.640 2.103.489.982 174.030.658 4.865.568 178.896.225
1625 36 Land an Land Rights
1626 DP S 45.675,442 44,418.223 1.257.219 1.257.219
1627 B8 45.675.442 44,418.223 1,257.219 1.257.219
1628182 361 Strs an Imprvement
163 DPW S 51,310.36 50,502.370 807.990 807.99
1631 B8 51.310.36 50.502.370 807.990 807.990
1632
163 362 Stati eqipment
163 DP S 683.432.277 657,449.397 25.982.880 25.982,880
183 B8 683,432.277 657.449,397 25,982.880 25.982.880
163
1637 36 Stoe Battery Equipent
1638 DPW S 1,457.805 1,457,805
1639 B8 1,457.805 1.457.805
164
1641 36 Pole, Towrs & Fixtres
1642 DPW S 83.589.385 781.679.850 54.909.535 54,909.535
184 B8 836.589.385 781.679.850 54.909.535 54.909.535
164
1645 36 Overh Conducrs
164 DPW S 603.343.307 570.596.981 32,746.326 32.746.326
1647 B8 603.343,307 570,596.981 32.746.326 32,746.326
1648
ROLLED.IN Page 9.26
Vear-End
FERC BUS UNADUSTED RESUlTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
164 36 Unergund Conduit
1650 DP S 267.664.461 26.916.997 6.747.46 6.747.464
1651 B8 267,664.461 26.916.997 6.747.464 6,747,464
165
1653
165
165
165 367 Unund Conducrs
1657 OPW S 64.487,853 620.397.210 22.09.643 22.09.643
165 B8 642.487.853 620.397.210 22,090.643 22.090.643
165
1660 36 Line Transers
1661 DP S 96.35.257 902.743.891 60.612.365 60.612.365
166 B8 96.35.257 902.743.891 60.612.36 60.612.365
166
166 369 servic
166 OPW S 503.373.33 478.582.329 24.791.003 24.791.003
1666 B8 50.373.333 478.582.329 24.791.003 24.791.003
1667
166 370 Meters
1669 OPW S 164.224.195 170.48.808 13.735,388 13.735.388
1670 B8 164.224.195 170.48.808 13.735.388 13,735.388
1671
1672 371 Instatins on Customers' Premises
1673 OPW S 8.86.604 8,700.244 160.36 160.360
1674 B8 8.86.604 8.700.244 160.360 160.360
1675
1676 372 Le pro
1677 OPW S 49.658 44.785 4.873 4.873
1678 88 49.658 44.785 4.873 4.873
1679
1680 373 Strt Ligts
1681 OPW S 59.329.899 58.742.967 566.732 58.732
1682 B8 59.329.699 58,742.967 586.732 58,732
1683
1684 DP Unifed Dlst Plant. Acc 30
1685 DP S 33.108.283 31.161.289 1.946.994 1.94.994
1686 B8 33.108.283 31.161,289 1.946,994 1.946.994
1687
168 050 Unssif Olst Sub Plant. Acet 300
1689 OPW S
169 B8
1691
1692169 Totl Disbuton Plant sa 4,88,262.918 4,637,883,146 246.379.772 246,379,772
1694
169 Summary of Distr Plat by Factr
1696 S 4,88,262.918 4.637,88.146 248.379.772 246.379.772
1697
1698 Tota Diut Plant by Fact 4,884.262.918 4,637.883.146 246.379.77 246.379.772
ROLLEO-IN Page 9.27
Ve.r-End
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
169 389 Land anc Land Rights
1700 G-SITU5 5 8.55.822 8.35.183 197.639 197.639
1701 CU5T CN 1.128.506 1.082.64 45.860 45.86
1702 PT 5G 332 312 20 20
1703 G-SG 5G 1.228 1.153 74 74
1704 PTO SO 5.59.055 5,275.44 32.60 322.609
1705 B8 15.283.942 14.717.741 58.201 566.201
1706
1707 39 Stre and Imprvements
1708 G-U5 5 104.99.163 95.169.127 9.821.056 9.821.056
1709 PT 5G 358.127 33.46 21.659 21.65
1710 PT 5G 1.573.572 1.478.404 95.169 95169
1711 CUST CN 12.05.264 11.56.327 48.937 48.937
1712 G-SG 4.061.516 3.815.878 245.63 245.638
1713 PT 50 103.687.865 97.712.469 5.975.396 5.975.39
1714 B8 22.727.527 210.078.672 16.648.855 16.48.855
1715
1716 391 Of Furnure & Equipment
1717 G-ITU5 5 14.820.180 13.681.914 93.266 93.266
1718 PT 5G 277.657 260.86 16.793 16.793
1719 PT 5G 281.018 26.022 16.99 16.99
1720 CU5T CN 6.30.109 6.04.84 25.265 256.265
1721 G-G SG 4.882.96 4.587.649 29.319 295,319
1722 P SE 172,221 160.878 11.343 11.343
1723 PTD SO 69.168.973 65.182.85 3.986.117 3.98.117
1724 G-G SG 22.027 211.418 13.610 13.610
1725 G-G SG 13.466 12.652 814 814
1726 B8 96.147.619 90.612.097 5.53.522 5.535.522
1727
1728 392 Trapotion Equipment
1729 G-SITUS 5 69.741.603 64.957.848 4.783.95 4.783.95
173 PTO SO 8.313.30 7.83.220 479.085 479.085
1731 G-SG SG 14.98.637 14.078.376 90.262 90.2
1732 CUST CN
1733 PT SG 1.08.011 947.047 60.96 60.98
1734 P SE 752.743 703.164 49,579 49.579
1735 PT SG 155.978 146.54 9.433 9.43
1736 G-SG SG 359.606 337.657 21.749 21.749
1737 PT SG 44.655 41.954 2.701 2.701
1738 B8 95.36.737 89.047.010 6.313.727 6.313.727
1739
1740 393 Stos eqipent
1741 G-ITUS S 8.914.812 8.278.705 636.107 63.107
1742 PT SG 335.531 315.238 20.29 20.293
1743 PT SG 673.399 63.672 40.727 40.727
1744 PTO 50 49.538 46.038 28.50 28.50
1745 G-G SG 2.928.003 2.750.919 177.08 177.084
1746 PT SG 106.993 100.522 6.471 6.471
1747 B8 13.45.276 12.544.096 909.181 909.181
ROLED-N Page 9.28
Yea-End
FEC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1748
1749 39 Too, Shp & Garge Equipment
1750 G-ITUS S 31,213.775 29.592.373 1,621,402 1,621.402
1751 PT SG 2,809,419 2.639.507 169.912 169.912
1752 G-G SG 18.089.337 16.99.305 1,09,032 1.09.032
1753 PTO SO 4.130.587 3,892.546 238,040 238.04
1754 P SE 7,106 6.63 46 46
1755 PT SG 4.318,672 4.057.482 261.191 261.191
1758 GoSG SG 1.79.459 1,689.690 108.770 108.770
1757 G-SG 74.831 70.305 4.526 4.526
1758 as 62.442.187 58.943,846 3.498.340 3,498.340
1759
1760 395 Laborary Equpment
1761 G-US S 27,659.613 26.316,059 1.34.55 1.343.554
1762 PT SG 60,181 56.541 3.64 3.40
1763 PT SG 827.868 777,799 50.06 50,06
1764 PTO SO 5,474,088 5.158.623 315,46 315.46
1765 P SE 42.438 39.64 2,795 2.795
1768 G-SG 5.746.607 5,399.056 347,551 347.551
1767 G-SG 253,001 237.699 15,301 15.301
1768 G-G SG 110,119 103.459 6,66 6.660
1769 as 40.173,914 38.088,880 2.085.035 2.085.035
1770
1771 39 Powr Opte Equipment
1772 G-ITUS S 89.728.297 83.140.656 6.587,641 6.587,641
1773 PT SG 981.699 922.327 59.373 59.373
1774 G-G SG 27.00.474 25,373.139 1.83.335 1,83.33
1775 PTD SO 1.676.426 1,579.816 96.610 96.610
1776 PT SG 2,088.671 1,962.349 126,322 126.322
1777 P SE 73.823 68.961 4,862 4.862
1778 P SG
1779 G-G SG 724.64 66.821 43,826 43.826
1780 as 122.280.37 113.728.069 8.551.968 8.551.968
1781 397 Communic Equpment
1782 COM_Ea S 106,217.120 100.038,244 6.178.876 6.178,76
1783 COM_EO SG 5,569.387 5.232.554 338.83 33.833
1764 COM_Ea SG 10,751,58 10,101.336 65,249 65.249
1785 COM_Ea SO 49.796.807 46.927.082 2.869.725 289,217 3.158.942
1768 COM_Ea CN 4,520.30 4.336.612 183.694 183,694
1787 COM_Ea SG 82.831.44 59.031.437 3,00.007 3,80,007
1788 COM_Ea SE 113,108 105,658 7.45 7.45
1789 COM_Ea SG 952.959 89.325 57.63 57.634
1790 COM_Ea SG 87.578 82.282 5.297 5.297
1791 as 240.840.294 226.750.529 14.089.764 289.217 14,378.981
1792
179 39 MI. Equient
1794 G-ITUS S 1,144,675 1,08.959 60.718 60.716
179 PT SG 18.689 17.559 1,130 1,130
1796 PT SG 25.819 24.258 1.562 1.562
1797 CUST CN 197.26 189.244 8.016 8.016
179 PTO SO 3,20.731 3,021.931 184.80 184.80
179 P SE 3,531 3.29 23 23
1800 G-SG 1.13,737 1.234.28 79,45 79.45
1801 G-SG 2.65 2.49 160 160
1802 as 5,913,093 5.577022 336.071 336.071
180
180 399 CoalMle
1805 P SE 262,931,404 245.613,524 17.317.881 11.462.753 28.80.834
1806 MP P SE
1807 as 262.931.404 245.613.524 17.317.881 11.482.753 28.800.634
180
180 39 WIDCO Capitl Lease
1810 P SE as
1811
1812
1813 Remove-capi Leases
1814 88
1815
ROLLED-N Page 9.29
Vear-End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1816 101139l General Capital Leases
1817 G-SITUS S 7.30,030 7.306,30
1818 P SG 12.411,745 11,661.090 750.655 750.655
1819 PTO SO 12.902,451 12.158,899 743,551 743.551
1820 89 32.620.226 31.126.020 1.494.206 1.49.206
1821
1822 Reove Capit Leases (32.620.226)(31.126.020)(1.494.206)(1,494.206)
1823
1824
1825 101134 Ge Gas Un Cata Leases
1826 P SG
1827 B9
1828
1829 Remve Ca Leases
183
1831
1832 GP Unclasifi Ge Plat - Ac 30
1833 G-ITUS S
1834 PTO SO 692.740 652.818 39.922 39.922
183 CUST CN
1836 G-SG
1837 PT SG
1838 PT SG
183 88 692.740 652.818 39,922 39.922
184
1841 399 Unassied Ge Plant - Acc 30
1842 G-ITUS S
1843 PTO SO
184 G-SG SG
1845 PT SG
184 PT SG
1847 B8
1848184 Totl Geeral Plant B8 1,182.246.771 1,106,354,304 75,892.468 11,771,970 87,664.438
1850
1851 Sumary of Gene Plnt by Faer
1852 S 470.292.309 43,123.098 32.169.211 32.169.211
1853 DGP
1854 DGU
185 SG 191.127,303 179.568,42 11.559.26 11.559.26
1856 SO 265.142.565 249.862,746 15.279.819 289.217 15.569.036
1857 SE 28.09.376 246.701.765 17,394.611 11,482.753 28,877,364
185 CN 24.208,44 23,224,673 98,772 983.772
185 DEU
186 SSGCT
1861 SSCH
1862 Less Captal Leases m2,62O.228)f31.126.020)
~1.494.206)~1.494.206)
186 Tota Gen Plant by Facor 1, ì2.246, 77 1.116,354,304 5.892.468 11.17.970 1.664.438
186 301 Organizti
1865 I-ITUS S
186 PTO SO
1867 I-SG
1868 B8
186 302 Frase & Conse
1870 1-SITUS S 1.00,00 1.00,000 1.00,00
1871 I-G SG 2.94.25 2.767.129 178.127 2.56.008 2.744.135
1872 I-G SG 60.58,96 56.925.517 3.664.44 3.86.44
1873 I-SG 9.240.742 8.681.867 558.874 55.874
1874 P SG
1875 P SG 60.99 58.645 36.348 36,348
1876 B8 74.376.951 68.939,158 5.437.792 2.566.008 8.003.800
1877
ROLLED-IN Page 9.30
Yea-End
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1878 303 Miscellaneous Intangible Plant
1879 I-ITUS S 1,537.927 1.145.546 392,381 392.381
1880 I-G SG 63,04.863 59.228.190 3,812.672 3.812.672
1881 PTO SO 378.024.43 356,239.381 21,785.054 21,785.054
1882 P SE 3.60.044 3.362.929 237.116 237,116
188 CUST CN 108.710.99 104.293.246 4,417.750 4,417.750
188 P SG 34.575 323.736 20.84 20.84
188 P SG -
1888 B8 555.258.839 524.593.028 30.665.812 3õ.665.812
1887 303 Less Non-llit Plant
188 1-SITUS S
1889 555,258.839 524.593.028 30.665,812 30.665.812
1890 IP Unclassifi Intngibl Plant - Ac 300
1891 1-SITUS S
1892 I-SG SG
1893 P SG
1894 PTD SO
1895
1896
1897 Totl Intangible Plant B8 629.635,790 593,532,186 36,103,604 2,566,008 38,669.612
1898
1899 Summar of Intagibl Plant by Facor
190 S 2,537,927 1.145.546 1.392.381 1,39.381
1901 DGP
1902 DGU
1903 SG 136,762.389 128,491.085 8,271.304 2.586.008 10.837.312
190 SO 378.024.435 356.239.381 21.785.054 21,785.54
1905 CN 108.710,995 104.293.246 4,417.750 4.417,750
190 SSGCT
1907 SSCH
1908 SE 3,60.044 3.362.929 237.116 237.116
1909 Tot Intagible Plant by Facor 62,635.790 593.532.186 36.103.604 2.566.008 38.669.612
1910 Summar of Unclassifed Plant (Acct 106)
1911 DP 33.108.283 31.161.289 1.94.99 1.946.994
1912 DSO
1913 GP 892.740 852.818 39.922 39.922
1914 HP
1915 NP
1916 OP
1917 TP 21.93.847 20.60,483 1.328.36 1.32.364
1918 TSO
1919 IP
1920 MP
1921 SP 526.307 494,476 31.831 31.831
1922 Tota Unclassifid Plant by Facr 56.258.176 52.913,066 3.345.110 3.345.110
1923
1924 Totl Elecc Plant In Servce B8 16,347,947.992 15,405.837,138 942,110.853 71.192.357 1.013.303.211
ROLLED.IN Pag 9.31
Vear-End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1925 Summai of Elect Plant by Factr
1926 S 5.357.093.153 5.077,151,790 279.941,364 279.941.364
1927 SE 267.696,421 250,06,694 17,631.727 11,482,753 29.114.48
1928 DGU
1929 DGP
193 SG 9,979.692.204 9.376.126.63 603.56.574 59.420.387 662.985.962
1931 SO 64,167.00 606,102.127 37.06.873 289.217 37.354,090
1932 CN 132,919.44 127,517.918 5.401.522 5,401,522
1933 DEU
1934 SSCH
1935 SSGCT
1936 Less Capital Leases ~32.62O.226)ß1.126.02O)J1.494.206)
.
l1.494.206)
1937 16. 47.947.992 15. 5.837.138 2.110.853 71.192.357 1.0 3.303.211
1938 105 Plant Held For Future Use
1939 DP S 505.024 505.024
194 P SNPPS
1941 T SNPT 12,239,128 11.498,913 740.215 (740.215)0
1942 P SNPP
1943 P SE 95.014 890,244 62.nO (62.710)(0)
194 G SNPG
194
194
1947 Totl Plant Held For Future Use B10 13,697,167 12,894.182 802.985 (82,85)0
194
1949 114 Elec Plant Acquisitin Adjustments
195 p S
1951 P SG 142.633.069 134.00.710 8,826.359 8.62.359
1952 P SG 14.56.711 13.68.088 880.623 880.623
1953 Tot Elecric Plant AcquIsitIon Adjustment B15 157.193.780 141,686.798 9,506,982 9,506.982
1954
1955 115 Acum Proision for Ast Acqisi Adustments
195 P S
1957 P SG (74.46,702)(69,962.063)(4.503.639)(4.503.639)
195 P SG
l10.902.465)l10.243.091 )
(659.374)(659.374)
1959 B15 85.368.167)80.205.153)(5.163.014)(5.163.014)
196
.1961 120 Nucar Fue
1962 P SE
1963 Totl Nuclear Fuel B15
196
1965 124 Wearition
1966 DMC S 4,417,918 4.378.819 39.09 39.09
1967 DMSC SO l2.463)42.321)
(142)(142)
1968 B16 4,4 5.455 4.36.498 38.957 38,957
196
1970 182W Weaerition
1971 DMSC S 6,475,25 921.54 5.55.48 5.553.48
1972 DMS SG
1973 DMSC SG
1974 DMC SO ....
1975 B16 6.475.025 921.544 5.553.480 5.553.480
1976
1977 166W Weattin
1978 DMSC S
1979 DMC CN
198 DMC CNP
1981 DMC SG
1982 DMC SO
198 B16
1984198 Totl Weatheriation B16 10,890,479 5,29,042 5,592,437 5,592.437
ROLLED-lN
Page 9.32
Vear-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
198
1987 151 Fue Stok
198 P DEU
1989 P SE 93.079.685 86.949.026 6.130.659 1.183,137 7.313,796
199 P SE
1991 P SE 5.254.497 4,908,411 34.085 346,085
199 Totl Fuel Stock B13 98,334.182 91,857.437 6,476,745 1,183.137 7,659.882
1993
199 152 Fuel Stock. Unstrbued
1995 P SE
1996
1997
199 25316 00& T Worin Capital Deposit
199 P SE (551.000)
1514.7091
(36.291)(36.291)
20 813 (551,000)514.709 (36.291)(36.291)
201
202 25317 OOT Worin Capit Depoit
203 P SE (1.54,1441
11.442.44)
(101.704)(101.704)
20 813 (1.54,144 1.442.44)(101.704)(101.704)
200520 25319 Pro Woring Capit Deposit
207 P SE
20820
2010 Total Fue Stock 813 96.239.038 89.900.289 6.338,749 1.183.137 7.521.886
2011 154 Mateals and Supplies
2012 MSS S 75,379.082 70.917.669 4,461,413 4.461.413
2013 MSS SG 1.807.015 1,697.727 109.287 109.287
2014 MSS SE 4.314.408 4.03.241 284.167 28.167
2015 MSS SO 194.683 183,464 11,219 11.219
2016 MS SNPPS 73.22.690 68.797.985 4.428,705 4,428.705
2017 MS SNPPH (21.081)(19.806)(1.275)(1,275)
2018 MSS SNPD (4.850.776)(4;623.640)(227.136)(27.136)
2019 MS SNPT
2020 MSS SG
2021 MSS SG
2022 MS SNPPS
2023 MS SNPP
2024 MSS SNPPS
2025 Totl Materials and Supplies B13 150.050.022 140,983,641 9,066,381 9,066.381
2026
2027 163 Stos Exnse Undistrbued
2028 MS SO
2029
2030 813
2031202 2518 Provo Working Capi Deposit
203 MS SNPPS (273.00)(25.489)(16.511)(16.511)
2034
2035 813 (273.000)(25.489)(16.511)(16,511)
2036
2037 Total Materials & Supplies 813 149.777.022 140.727.152 9.049.870 9.049.870
2038
2039 165 Preyments20DMSC S 3,232,469 3,058.96 173.502 173,502
2041 GP GPS 8.147.93 7.678,378 46.555 46.555
2042 PT SG 5.05.50 4.148,813 305.693 30.693
2043 P SE 3,641.353 3.401.516 239,836 23,836
20 PTD SO 19,220.698 18.113.035 1.107.66 1,107.664
2045 Tot Prepayment B15 39.296.959 37.000.708 2.296.251 2,296.251
2046
ROLED-N Page 9.33
Yea-E
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
207 182M Mi Regulatory Assets
2048 0052 S 58,43,687 58,721,817 (287,130)(28.865)(315.995)
2049 OEFSG SG 7,092,836 6.66,86 428,970 (68,181)360.789
2050 P SGCT 10,756.573 10,103,447 65,126 653126
2051 OEFSG SG20PSE20PSG
2054 00502 SO 7,055.54 6,64.942 40.602 40.602
20 811 83,339.641 82,138,02 1.201.568 (97.046)1,104.522
20
2057 186 Mis Defe Debits20LAOR S 4,22,084 4,22.084
209 P SG20PSG
201 OEFSG SG 39,49,834 37.102,45 2,388,381 2,38,381
202 LAR SO 97,769 92,134 5.634 5.63
20 P SE ø.3O,427 5,63,23 397,192 142.349 53.541
2064 P SNPPS20GPEXCTAX .
20 Tot Misc. Deferr Debit B11 49.839.11 47,047.906 2;91,207 142.349 2,933.557
20720 Worin Cal20ewcCa Worin Capita
2070 ewc S 44.48,692 42,175,964 2,37.708 1,144,381 3,452.09
2071 ew SO
2072 ewc SE
2073 814 44.48.692 42,175.984 2,307.708 1.144.381 3.452,090
2074
2075 OWC 0l Wo Ca.
2076 131 e-GP SNP 22.99.473 21.702,310 1,297.163 (1,27,163)
2077 135 WOf Fu GP SG 2.691 2,528 163 163
2078 141 .- R- GP SO 918,46 86.530 52,930 52.930
2079 143 0lNF GP SO 16,607,23 15.65.177 957.053 957,053
2060 232 Al PTD S
2081 232 Al PT SO (1,278.89)(1.20.194)(73.701)(73,701)
2082 23 Al P SE (1,21ø.83)(1.135.98)(60.097)(60,097)
20 23 Al T SG 2 2 0 0
20 253 aa -. Il. eN P S2025aa -'il. eN P SE (5.605,322)(5,23.130)(369.192)(369.192)
20 230 __.OIP SE (2.401,44)(2,243,273)(158.170)(158,170)
207 230 __.oiioP S
208 25105 AR..Li P S (30,363)(30.36)
2089 254105 AR..1. P SE (437,40)(40,596)(28,810)(28,10)
20 25 -_P SE
201 814 29,55.343 27,961.005 1.597,338 (1.297,163)300.175
2020 Tot Working Capitl B14 74,042,035 70,136,989 3,905.046 (152.781)3,752,265
20 MlHaneus Rate 8as201821Un Pla & Reg Study Cots20PS
209720 81520
2100 1822 Nuc Plan . Tron
2101 p S (1.059,80)(1.059.80)
2102 P TROJP 2.519.60 2.365,155 154.44 154.44
2103 P TROJO 3.68.386 3.462.703 22.683 226.683
2104 815 5,149.186 4,768.058 381.128 381,128
2105
2106
ROLLED-N Page 9.34
Year.End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAH ADUSTMENT ADTOTAL
2107
2108 1869 Mise Defert Debits-Tron
2109 P 5
2110 P 5NPPN
2111 815
2112
2113 Totl Miscellaneous Rate Base 815 5.149.186 4,768.058 381.128 381.128
2114
2115 Totl Rate Base Additions B15 59.096.252 557.393.043 36.703.210 272.674 36,975.883
2116 23 Customer Servic Deposits
2117 CU5T 5
2118 CU5T CN
2119 Tot Customer Service Deposits 815
2120
2121 2281 Prp Ins PTD 50
2122 2282 Inj & Dam pro 50 (6.054.192)(5.705.297)(348.895)(34.895)
2123 2283 Pe & Ben pro 50 (20.38.756)(19.211.894)(1.174.862)(1.174.862)
2124 254 RegUab PTD 5G (52.919)(52.919)
2125 25 RegLiab pro 5E (101.06)(101.068)
2126 25 InsProv PTD 50 -..
2127 815 (26,44.948)(24.917.191)(1.523, 757)(153.987)(1,677, 744)
2128
2129 22 Ac Hy Relicnsing Obligation
2130 P 5
2131 P 5G
2132 815
2133
2134 22842 PrvTroja P TROJO (2.48.00)(2.331.387)(152.622)(15262)
2135 230 ARO P TROJP (2.273.792)(2.134.414)(139.378)(139.378)
2136 25105 ARO P TROP (86.813)(812.741)(53.072)(53072)
2137 25 P 5 251.99 251.99 -.
2138 815 (5.371.617)(5.026.545)(34,02)(345,02)
2139
2140 252 Custer Adnces fo Coon
2141 OPW 5 (17.214.233)(17.184.55)(49.679)(126.145)(175.824)
2142 OPW 5E
2143 T 5G (3.54.873)(3,3.542)(214,331)(109,51)(323832)
2144 DP 50
2145 CU5r CN 3.272.317 3.139.338 132.979 132.979)0
2146 Totl Customer Adances for Constructon B19 .7 9 .7 .1 . 25
2147
2148 25398 502 Emiss
2149 P 5E p.682.541)g.682.541)
2150 819 .682.541).682,541)
2151
2152 25 Otr Dert Credit
2153 P 5 (4.993.839)(4.917.88)(75.954)(75.954)
2154 LAOR 50 (532.374)(501.694)(30.68)(885.756)(916.43)
2155 P 5G (19.09.719)(17.93.882)(1.154.837)(86.587)(1.241.424)
2156 P 5E ~2.732.187l ~2.552.233)(179.95l .(179.955)
2157 819 (1.353.120 ( 5.911.695)(1.441.425 (972.343)(2.413.767)
ROLLED-IN Page 9.35
V...end
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL
2158
2159 190 Acumulate Defene Ince Taxs
2160 P S 8,073,135 7,567.003 50,132 (175.772)33.360
2161 CUST CN 112,198 107,638 4.559 (968)3.592
2162 P IBT 34,847 34,847
2163 LABOR SO 40,281,864 37,96,473 2.321.391 1,477.94 3,799,33
2184 P DG 36 36
2165 CUST BAOEBT 2.39._2.737,051 102.44 (68.09)34.351
2166 P TROJO 137 128 8 (901)(89
2167 P SG 42.278,827 39,721.829 2,55.997 262.489 2.819,486
2168 P SE 17,35.183 16.213,025 1,143,159 997,36 2,140.522
2169 PTO SNP (0)(0)(0)(1.202)(1.202)
2170 DP SNPO 767,198 731,275 35.924 806 36.730
2171 P SSGCT 2.505.335 2.351.247 154,088 154,088 308.176
2172 Tol Accum Derr Income Taxes 819 114,214.740 107,390.37 6,824.704 2,680.601 9,505.305
2173
2174 281 Acum Oene Ince Taxes
2175 P S
2176 PT OGP
2177 T SNPT
2178 B19
2179
2180 282 Aculate Defene Inc Tax
2181 GP S (4,587,219)(4,078.150)(509.069)(83,432.38)(83.941.449)
2182 ACCMOIT OlTBAL (1,307.98,45)(1,22.104.997)(81.878.459)79.277,282 (2,601.177)
2183 PT GPS (58)(58)
2184 LABOR SO (14.601,54)(13.760.075)(841.46)(148,882)(99.35)
2185 PTO SNP
2186 P SE (13,070,44)(12,29.568)(86o,80)(49.190)(910.70)
2187 P SG (12,619.089)(11.855.894)(763.195)(67.997)(831.192)
2188 B19 (1.352.861.755)(1.26.008.684)(84.853.071)(4,421.225)(89.274.295)
2189
2190 28 Acul Oene Ince Taxes
2191 GP S (34.929.383)(34.179.121)(750.262)698.111 (52.151)
2192 P SG (9.709.40)(9.122,190)(587.219)94.807 (492.412)
2193 P SE (16.716.219)(15.615.212)(1.101.008)130,483 (970,52)
2194 LAR SO (4.758.518)(4.482,404)(274.112)(36.59)(310.70)
2195 GP GPS (14.06.062)(13,249,818)(810.26)30,633 (779,631)
2196 PTO SNP (7.94.83)(7.495.809)(44.030)99,567 (34.463)
2197 P TROJO 180.05 168.98 11.06 35,737 48,799
2196 P SG
2199 P SG (2.907.765)(2,731.90)(175,60)21,629 (154.231)
220 P SG
221 B19 (90.84.163)(86.707,471)(4,135,692)1.074.372 (3.061.320 )
222223 Totl Acum Der.rr Ince Tax B19 (1,329.490,178)(1,247,326.119)(82,164,059)(66.251)(62.830.310)
224 25 Acimulte Invstment Tax Credi22PTOS
228 PTO 1TC84 (2.90.86)(2.90.865)
227 PT 1TC85 (4.401,706)(4.401.708)22 PTO 1TC86 (1.973.007)(1.973.007)22 PTO 1TC88 (281.502)(281,502)
2210 PT ITC89 (60,588)(604.58)
2211 PT ITC90 (373,45)(321,43)(52,215)10,228 (41.987)
2212 PTO IBT .-.
1114.3511 f14,351l2213Totl Acumlated ITC B19 (10.543.126)(10.49.911 )(52.215)104.123 156.338
2214
2215 Totl Rate Base Deuctons (1,416.684.777)(1,331.027.218)(85,657.560)(4.947.869)(90.605.429)
2216
ROLLED-N Page 9.36
Vur-End
FERC BUS UNADUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADTOTAL
2217
228
2219 108 St Pro Plat Accumulated Depr22PS
221 P SG (846.57.975)(79.88,915)(51,169.06)(51.16906)
22 P SG (90,037.747)(85,120,189)(54.917.55)(54.917,55)
22 p SG (482.328.111 )(45,157,27)(29.170,904)(22,55)(29,373.457)
224 P SG (218.29.175)(20.09,577)(13,202.598)(13,202.598)
22 817 (2,454.723.008ì (2,3.262.888)(148.460.120)(202.553)(148.662.673)
2226
2227 108 Nuler Pro Pl Accumulted Depr
222 P SG22PSG22PSG
2231 8172222
2234 108HP Hyli Pro Plant Acum Depr22PS
2236 P SG (142.234.2n)(133.83,032)(8,602.240)(8,602,240)
227 P SG (28.034.185)(26.33.695)(1,69.49)(1.69.490)
22 P SG (53.207.003)(49,98.077 (3,217,926)(37,179)(3,2,105)
22 p SG (7.634.571 )(7,172,837)(461.73)(461.734)
2240 817 (231.110.031ì (217,132.640)(13.977.391)(37,179)(14.014.570)
2241
2242 108 Ot Prucion Plant. Acc Depr
2243 P S
2244 P SG (1,911,321)(1,795,726)(115.96)(115.59)
2245 P SG
2248 P SG (87,527.55)(82.233.941 )(5,23.612)(1.274.96)(6,56577)
227 P SG (15,816,540)(14.859.966)(956.575)(95.575)
2248 817 (105,255,415)(98.889.633)(6.365.782)(1.274.965)(7:&.747)
224922 108EP Exment Plant. Accm Depr221PSG22PSG2222225Totl Prouction Plant Accum Deiation 817 (2,791,088.453)(2,622,285.161)(168,803.293)(1,514,697)(170,317,990)
22227 Suar of Prod Plant Deiation by Facor22S
229 DGP22DGU
2261 SG (2,791,08,45)(2,62,285.161)(168,803,293)(1,514,697)(170.317.9)
222 SSCH
223 SSGCT --.-.
22 Totl of Pr Plt Deiati by Facr (2. 791.08. 453)(2.622.285.161 )(168.803.293)(1.514.697)(170.317.990)
2222227 108TP Trasmission Plan Accumulte Depr
2288 T SG (372,189,60)(22.50.796)
229 T SG (373,597,351)(22,594.935)
2270 T SG 332.247.238)20.094.106)
221 Totl Trans Plant Accum Depreiation 817 . 3 ,, 9 . 37
ROLLED-N Pag 9.37
Year-End
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADTOTAL
222 10836 Land and Land Rights
2273 DP 5 (5.413.495l (5,188.980)(22.515)(226.515)
2274 817 (5,188.980)(226.515)(226.515)
225
(5,413.95
2276 1081 5tru an Imprvements
2277 DP 5
f6.237,713)
(15,697,823)(539.890)(539.890)
228 817 (15.697,823)(539.890)(539.890)
2279
16.237,713)
22 1082 5tatl Equipent
2281 DP 5 (17.997.187l (164.377,105)(7.620.82)(7.620,082)
222 817 (164.371,105)(7,620.082)(7,620.082)
2283
(17.997.187
22 108 St Ba Equipment225DP 5 (827.98)(827.985)
228 817 (827.985)(827,985)
228722 10836 Pol, Tow & Fixs
2289 DP 5
l44.329.666)
(418.164,425)(25.145,241 )(25.145.241 )
22 817 44.329.666)(418.184.425)(25.145.241 )(25,145.241)
221222 108 Ovad Coctor
2293 DP 5 250,497.09)
224 817 25.497.098
225
229 108 Undrgun Cond
227 DPW 5 (112.289.079)(108,994.948)(3.294,132)(3.29,132)
229 B17 (112,289.079í (108.994.948)(3.294.132)(3,294,132)
22
230 1087 Unroun Coductors
2301 DPW 5
f231,621.244l
(22.966.376)(10,854.868)(1D.54.868)
232 817 231,621.244 (22.966.376)(10,854.868)(10.654.8681
233
234 10836 Une Transfoer23DPW 5 (357,083.811 )(329.931.490)(27.152.321)(27,152,321 )
23 817 (357,083.8111 (329.931,490)(27.152.321)(27.152.321 )
23723 1083 Seics
230 DP 5 (150,691.618)(139.772.013)(10.919.60)(10.919.606)
2310 B17 (150.691.618)(,39.772.013)(10,919,606)(10.919.606)
2311
2312 10870 Meters
2313 DP 5 m,569.631)(71.94.570)(5.625.61 )(5.625.061)
2314 817 (77,569.631)(71.944.570)(5.625.061 )(5,625.0611
2315
2316
2317
2318 10871 Intalas on Cusmers' Priss
2319 DPW 5
t923.008)
(5,764.615)(138.393)(138.393)
2320 B17 5.923,008)(5,784.615)(138,393)(138,393)
232123 10872 Lease Prrt
2323 DP 5
141,112l
(36,26)(4.68)(4,686)
234 B17 41.112 136.426)(4.686)(4.686)
2325
2326 108373 Stt lits
237 DP 5 (20.905.1571 (20.632.456)(272,701)(272.701)
2328 817 (20.905.157 (20.632,456)(272.701)(272.701)
232923 1080 Unlassd Dist Plant. Ac 30
2331 DP S
2332 81723
233 10805 Unlaif DIS! 5ub Plat. Ac 3023DP523 B17
237
2338 108 Uncif Di 5ub Plant. Acc 30
2339 DP 523 817
231
23223 Total Distrbution Plant Aceum Deprlallon B17 (1,84,427,806)(1,740,387,096)(104,040,710)(104,040,710)
2323 Sumary of Disbuti Plt Depr by Facr235 (1.84,427.806)(1.740,387,096)(104.04.710)(104.040.710)
23723 Total Dison Deretion by Facor 817 (1.844.427.806)(1.14.387,096)(104.040,710)(104.040.710)
ROLED-N Pag 9.38
V..,-End
FERC BU UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2349 108GP Genera Plant Accumulated Depr23G-ITUS S
2351 PT SG
232 PT SG23G-G SG
235 CUST CN
235 PTO SO (20.46)
23 P SE
2357 G-G SG
235 G-G SG
239 B17 20.46)
23
231
2362 108MP MIng Pl Acmulaèd Depr.
236 P S
2364 P SE 10.451.704)
2365 B17 (10.451.704)23 108MP Less cetr"a Sis Depration
2367 P S23 B17 (158.84.619)(148.232.915)(10.451.704)(10.451.704)
239
2370 1081390 Ac Depr. Capil Lease
2371 PTO SO B17
2372
2373
2374 Reve Cal Leases
2376 B17
2376
2377 108139 Acm De. Catal Lease
2378 P S
2379 P SE B17
238
231232 .Remove Ca Leases
233 B172323236Totl Genl Plant Acum Depriation 817 (471.013.725)(439.074.052)(31,939.674)(2.46)(31,96.133)
237
238823
2390 Summaiy of Ge Oeti by Facr
2391 S (148.928.702)(136.947.489)(11.981.213)(11,981.213)
2392 DGP
2393 DGU23SE (159.171.791)(148.687.99)(10.48792)(10.48.79)
2395 SO . (89.729.60)(84.55.601 )(5.170,99)(20.46)(5.191,45)
239 CN (6.170,38)(5.919.63)(25.749)(250.749)
2397 SG (67,013.249)(62,96,33)(4.052,920)(4.052,920)
2398 OEU23SSGCT
2400 SSGH
2401 Remove Capitl Leas ...
2402 Totl Geral Deati by Factor (471.013.725)(439.074.052)(31.939.674)(20.460)(31.960.133)
2403
240
2405 Totl Acum Depreciaon. Plant In Service B17 (6,184,56.183)(5,814.581,669)(369,982.514)(1.596.768)(371.579.282)
240 111SP Acum Prav fo Amort-Steam
2407 P 50
240 P 50
f623.695)f585.975)fT.721l l37.721)2409 B18 623.695)585.975)37.721 37.721)
2410
2411
2412 111GP Acc Prav fo Amorteneral
2413 G-TUS S (17.046.932)(17.046.932)
2414 CUST CN (1.979.017)(1.898.595)(80.422 (80,422)
2415 I-SG 50 (68.687)(643.278)(41.40)(41.40)
2416 PT SO (6.872.243)(6.476.20)(396.038)(39.038)
2417 P se ....
2418 B18 (26.582.878)(26.065.008)(517,80)(517.870)
2419
ROLDoN Pag 9.39
Yeand
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNe FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL
2420
2421 111HP Acc Prv fo Amort-Hyro
2422 P SG (34.515)(323.136)(20.84)(20.84)
2423 P SG
2424 P SG (4.159)(3.901)(252)(252)
2425 P SG (311.119)(292.36)(18.820)(18.820)
2426 B18 (659.914)(620.003)(39.911)(39.911)
2421
2428
2429 1111P Acem PlO fo Amor-lntlble Plant
243 I-SITUS S (134.912)(39.619)(695,233)(69233)
2431 P SG
2432 P SG (29.202)(281.106)(18.09)(18.09)
243 P SE (859.911)(803.213)(56.63)(56.63)
2434 t-SG (31.441.492)(29.539.930)(1.901.562)(38.851)(1.940.213)
243 i-G SG (10.582.599)(9.942.510)(64.029)(64.029)
243 I-S SG (2.491.681)(2.34.992)(150.696)(150.696)
2431 CUST CN (19.592.211 )(16.351.718)(3.234.433)(3.23.43)
243 P SG
2439 P SG (19.919)(18.71)(1.208)(1.208)
244 PT SO (248.321.716)(234.011.311)(14.310.459)(14.310.459)
2441 B18 (314.343.169)(353.335.415)(21.008.353)(38.651)(21.041.005)
244 1111P Les No Plnt
244 NUTIL OTH --.-.
24 (374.343. 769)(353.335.415)(21.008.353)(38.651)(21.047.005)
24424 111390 Acc Amtr - Capil Lease
2441 G-ITUS S
244 P SG
244 PTD SO
245
2451
2452 Re Ca i. Am
245
2454 Totl Ac:um ProisIon for AmrtIzation B18 (42.210.256)(380.606.400)(21.603.856)(38.651)(21.642.507)
245245
2451
245245 Su of Amorn by Fac248S (11.181.84)(11.086.610)(695.233)(89,233)
2481 DG
246 OGU
248 SE (859.911)(803.213)(56.63)(56.38)
246 SO (255.194.019)(240.481.521)(14.106.491)(14.106.491)
246 CN (81.511.228)(18.25.312)(3.314.85)(3.314.85)
246 SST
2461 SSGCH
246 SG (46.803.255)(43.912.623)(2,8.632)(38.651)(2.86.283)
2469 Less Cal Lease -.--
2410 Tot Prvisin For Amorton by Factor (402.210.256)(38.606.400)(21.603.856)(38.651)(21.642.507)
10
Idaho December 2007 General Rate Case
December 31, 2007 Historical Loads
Year-End Factors
Page 10.1
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FACTORS BAED ON DECEMBER 207 HISTORIAL LOAD
Idho Deber 207 General Rate Ca.e
COINCIDENTAL PEAKS
Mo
Jan-7FeJ7
Ma-G7
Pn-G7Ma7Joo7Jul7Pu7se70c7
Nov70e7
MoJan7
Feb-7
Mar-G7
Pn-G7Ma7Ju7Jul7Puse7
oc-G7Nov70e7
MoJan7FeJ7
Ma-G7
Pn-G7May7Ju7Jul7Pu7Sep70c7Nov0e7
MoJa7FeJ7
Ma-G7
Pn-G7Ma7Ju7Jul7Pu7se70c7Nov7De
Mon
Jan-7FeJ7
Mar-G7
Pn-G7May7Jun7Jul7Pu7se70c7N070e7
Da
16
2
1
30
31
20
10
14
4
31
28
. 11
Da
16
2
1
30
31
20
10
14
4
31
28
11
Da
16
2
1
30
31
20
10
14
4
31
28
11
Da TI16 802 801 19030 15031 1700
20 170010 1700
14 17004 16031 8028 18011 180
Day Tim16 802 801 19030 150
31 1700
20 170010 1700
14 17004 16031 8028 18011 180
Time8080
190
150
170
170
1700
1700
16080
180
160
I METERED LOADSlCPJ
I Non.FERC FERC
CA OR WA E.WY Tot UT 10 W.WY UT NETUT Total
178 2.84 789 1.22 3.228 43 152 28 3,2 8.64
163 2.68 793 1.04 3.137 462 149 25 3,112 8.433
160 2.311 641 1.027 3.139 387 144 27 3,112 7,80
125 1.748 470 915 3.197 451 131 31 3.166 7,037
150 2.150 631 894 3.20 64 127 30 3.179 7,80
159 2.163 678 981 4.123 64 138 40 4.083 8,87
160 2.60 754 989 4.424 701 141 43 4,381 9.n5
165 2.310 707 1.00 4.473 60 136 43 4,429 9.40
129 1,60 82 1.018 3.99 502 124 37 3.959 8.254
131 2,181 690 90 2,723 370 143 23 2.700 7.144
145 2.43 711 1.02 3.475 46 146 29 3.44 8.395
155 2.517 762 1.08 3.552 43 162 30 3.522 8.650
1821 27812 8.253 11.893 42,676 6,093 1,690 38 42,289 100.237
(less)
TI8080
190
150
1700
1700
1700
170
16080
180
180
Adlustments for Curtilments. Buv. Thah. and Load Na Lonaer Served fReductins to Load)
I NoiiFERC FERC -.
CA OR WA E.WY UT 10 W.WY UT NETUT Tot
----
---.
.-.-
---.
.-.-
(89).(89)(89)
(9)(71)(90)(160)
(88)(71)(88)(159)
(85)(71)(85)(156)
--..
-(71)-(71)
(92).(92)(92)
-..-44\283\-.144 721\--equals
I COINCIDENTAL PEAK SERVED FROM COMPANY RESOURCES
i Non-FERC FERC -.
CA OR WA E.WY UT 10 W.WY UT NETUT Totl
178 2.84 789 1.022 3,28 43 152 28 3,20 8,64
163 2.68 793 1,04 3,137 462 149 25 3.112 8.43
160 2.311 641 1,027 3.139 387 144 27 3,112 7,80
125 1.748 470 915 3,197 451 131 31 3.166 7,037
150 2.150 631 89 3.2 64 127 30 3.179 7,80
159 2.163 678 981 4.035 64 136 40 3.99 8,798
160 2.60 754 98 4,33 63 141 43 4.292 9.615
165 2.310 707 1.00 4.38 53 136 43 4.341 9.247
129 1.88 626 1.018 3.910 431 124 37 3.873 8.09
131 2.181 69 90 2.723 370 143 23 2.700 7.144
145 2.43 711 1.02 3.475 38 146 29 3.44 8.324
155 2.517 762 1.089 3.46 43 162 30 3,43 8,55
1,821 27.812 8,253 11893 42232 5,810 1,690 38 41,846 99,511
+ plus
Adiustrent for Ancillary Services Contrcts Includlna Reserves (Additions to Load)
i Non-FERC FERC i
CA OR WA E.WY UT 10 W.WY UT NETUT Totl
..-
.-.
.--
..-
-..
71 -71
71 .71
71 .71
71 -71
.-.
71 .71
...
....-35 .--35--equals
Time8060190
150
1700
1700
1700
1700
16080160
180
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (CP) . Prior to temperature adjustment I
i Non-FERC FERC I
CA OR WA -c E. WY UT 10 W.WY UT NETUT Total
178 2.84 789 1,022 3.228 43 152 28 3.200 8.64
163 2.68 793 1.04 3.137 46 149 25 3.112 8.433
160 2.311 641 1,027 3.139 387 144 27 3,112 7,80
125 1.748 470 915 3.197 451 131 31 3.166 7.037
150 2.150 631 89 3.20 64 127 30 3.179 7.80
159 2,163 678 981 4,03 717 136 40 3,99 8.86
160 2.60 754 98 4.33 701 141 43 4,22 9,68
165 2.310 707 1.00 4,38 60 136 43 4,341 9,318
129 1,88 82 1.018 3.910 502 124 37 3,873 8,169
131 2.181 69 90 2.723 370 143 23 2,700 7.144
145 2.43 711 1.020 3,475 46 146 29 3,44 8.395
155 2.517 762 1.069 3,460 43 162 30 3.43 8,556
1,821 27.812 8.253 11,893 42,232 6164 1,69 386 41,846 99,86
Pag 10.13
ALLOCTIONS USINT HISTORICAL LOADS
FACTORS BASD ON DECEMBER 207 HISTORICAL LOAD
Idho Deembe 207 Geerl Rate Case
COINCIDENTAL PES
Month
Jan7FelH
Mar'(7
Ap'(7
May.(7
Jun7JuJ7
Aug7Se70C.(
Nov'(7De7
MontJan7Feb7
Ma'(7
Apr'(7
May.(7Ju7
JuJ7Au7Sep7
0c'(7
No'(7De
MoJan7Feb7
Mar'(7
Ap'(7
May'(7
Jun-7
Jul.7Au7Se70c'(7No.(De7
MoJa7Feb7
Mar'(7
Ap'(7Ma7Ju7JuI7Aug7Se70c'(7
Nov'(7De7
MonthJa7Feb7
Mar'(7
Ap'(7
May.(7
Jun7JuI7Aug7Se70c'(7No.(De7
Da
16
2
1
30
31
20
10
14
4
31
28
11
Da
16
2
1
30
31
20
10
14
4
31
28
11
Da
18
2
1
30
31
20
10
14
4
31
28
11
Da
16
2
1
30
31
20
10
14
4
31
28
11
Day
16
2
1
30
31
20
10
14
4
31
28
11
Tim8080
190
150
1700
1700
1700
1700
16060
160
160
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (CP) . Prior to temperature adjustment I
I Non.FERC FERC i
CA oR WA E.WY UT 10 W.WY UT NETUT Total
178 2.84 789 1,02 3,228 430 152 28 3,200 8,84
163 2.88 793 1.04 3,137 46 149 25 3,112 8.43
160 2,311 641 1,02 3,139 387 144 27 3,112 7.60
125 1,748 470 915 3,197 451 131 31 3,166 7,037
150 2,150 631 89 3,20 64 127 30 3.179 7.80
159 2.163 678 981 4,03 717 136 40 3,99 8,869
160 2.60 754 989 4,335 701 141 43 4,292 9,68
165 2,310 707 1,00 4,385 60 136 43 4.341 9.318
129 1,86 62 1,018 3,910 50 124 37 3,873 8.169
131 2,181 69 90 2,723 370 143 23 2,700 7.144
145 2.43 711 1,02 3,475 46 148 29 3,44 8,395
155 2,517 76 1,06 3,46 43 162 30 3,43 8,55
1621 27812 8253 1189 42232 6164 1690 38 4184 9986
(less)
TI6060190150
1700
1700
1700
1700
16080
160
160
Adjuen fo Inc:menllrraatlon Lo C-i Prram Curtilment
I Non.FERC FERC
CA oR WA E.WY -or 10 W.WY UT NETUT Totl..
..
..
..
..
(115)(115)
(157)(157)
(101)(101)
(100)(100)..
..
..
....473 ...(473
equals
Tim8060190150
1700
1700
1700
1700
16080180180
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (CP)I
r Non.FERC FERC
CA OR WA E.WY UT 10 W.WY UT NETUT Tota
178 2.84 789 1,02 3,22 43 152 28 3.200 8.84
163 2.88 79 1,04 3,137 46 149 25 3,112 8,43
160 2,311 641 1,027 3.139 387 144 27 3.112 7,60
125 1,748 470 915 3.197 451 131 31 3.166 7,037
150 2.150 631 89 3,20 64 127 30 3,179 7,80
159 2,163 678 981 4,03 60 136 40 3,99 8,754
160 2.60 754 98 4,33 54 141 43 4,29 9,529
165 2,310 707 1.00 4,38 50 136 43 4,341 9.216
129 1.86 62 1.018 3,910 40 124 37 3,673 8.06
131 2.181 69 90 2.723 370 143 23 2,700 7.144
145 2,43 711 1,020 3,475 46 146 29 3,44 8.395
155 2,517 76 1,06 3,46 43 162 30 3,43 8,55
1821 27812 8253 11893 42232 5691 1690 386 4184 99392
(less)
TI6080190
150
1700
1700
1700
170016060
180180
Adent fo Coidel S- Peks TemDerature Adustent
I Non'¡ERC FERC i
CA OR WA E.WY UT 10 W.WY UT NETUT Total
(11)(164)(45)(12)(119)(23)(2).(119)(37)
(9)(151)(97)(28)(40)(5)(1).(40)(33)
(3)(58)(33)(14)(65)(12)(2).(65)(187)
(2)(14)(5)(12)(240)1 (1).(240)(274)
(11)(278)(120)11 (99)(5)(0).(99)(502)
(6)(248)(82)(21)(55)(12)(2).(553)(92)
(10)(315)(103)13 (150)(5)(1).(150)(571)
(4)(145)(60)12 (170)6 (0).(170)(31)
6 123 (12)(24)65 13 1 .65 171
3 64 (66)(8)44 (0)1 .44 38
(1)(36)(17)(4)(62)(11)(1).(62)(132)
1 32 (46)(25)(39)(13)(1).(39)(89)
(46 1211 68\113 1428 (671 9 .11428\135581
equals
Tim6080
190
150170
1700170
1700
16080
180160
r NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (CP)1
i Non.FERC FERC I
CA OR WA E.WY UT 10 W.WY UT NETUT Tot
167 2,66 744 1,010 3,108 407 150 28 3.081 8.247
154 2,53 69 1,015 3,097 457 149 25 3,071 8,101
157 2,253 60 1,012 3,074 375 142 27 3,047 7.82
123 1.73 46 90 2,957 45 130 31 2.926 6,763
140 1,871 511 90 3,110 63 127 30 3,060 7,30
153 1,916 597 96 3,46 59 134 40 3,44 7,83
151 2.29 651 1,00 4.164 53 140 43 4,141 8,58
161 2,165 647 1,02 4,215 512 135 43 4.171 8,855
135 1,98 614 99 3,975 415 125 37 3,93 8,240
134 2,245 624 898 2,767 370 144 23 2.744 7,182
143 2,40 69 1,016 3,413 449 144 29 3,38 8,26
157 2,549 716 1,04 3.421 420 161 30 3,39 8,469
1775 26601 756 11760 40804 5624 1661 386 40418 9583
Pag 10.14
ALLOCTIONS USING HISTORICAL LOADS
FACTO BAED ON DECEMBER 2007 HISTORICAL LOAD
icaho Deember 2007 Generl Rate Case
ENERGY
Yfl Mo207 Jan1207 Feb7
207 Mar-G7207 Ar-G7207 Ma7207 Ju207 Ju7207 Au720 Se720 0d207 N07207 De7
Yea Mo207 Jan207 Feb7207 Ma-0
207 Ar-G7207 Ma7207 Ju207 JuI7207 Au72007 Se
207 Oc-G72007 N072007 De7
Yea Mon207 Ja7207 Feb7
207 Mar-G720 Ar-G7207 Ma207 Jun720 JuI720 Au7207 Se7207 0C7207 N072007 De7
Year Mon
2007 Jan7
2007 Feb7
2007 Ma-G72007 Ar-0200 May7207 Jun72007 Jul-7207 Au7207 Se7
207 oe-G72007 N072007 De7
Yfl Mo207 Ja7
2007 Feb7
2007 Ma-G7
207 Ar-G7207 May72007 Jun-7207 JuI7207 Au7207 Se7
207 Oc-G7207 N07207 De7
I METERED LOADS (MWHIrNon.FERC FERC I
CA OR WA E.WY Tot UT 10 W.WY UT NetUT Tot
97.192 1,572,33 461.73 715.08 2,113.473 29.94 99.86 17.410 2.09,06 5.35.631
82.86 1.291.88 371.626 628.94 1,810.68 224,266 89.442 14,496 1.796.190 4.50.716
97,215 1.26.162 353.79 68.825 1.80.206 250,763 94.423 15.679 1.784.528 4.525.392
87.951 1.170.197 324,757 621.20 1.719.957 251.970 90.381 15.43 1.704.524 4.26,420
92.263 1.20.89 311.841 63.787 1.918.429 38,08 93.54 17.398 1.901.031 4.84,841
93.106 1.193.34 34.371 64.991 2.112.03 447,449 92.020 19.402 2.092,631 4.926,316
91.89 1.33,26 411,50 683,65 2.50.08 461.357 97.139 23.38 2.476.721 5.578,706
93.60 1.30,327 38,54 66,158 2.428,152 357,794 94.43 22.94 2.40.206 5.35,017
74,89 1.181.39 35.019 65.342 1,927,54 30,751 86.712 17.370 1.910.170 4.577.652
78.582 1,40.775 38.128 65.33 1.84.702 265,181 96.972 15.753 1.82,949 4.55.65
80.05 1,331.073 391.731 682,29 1,94.814 271.86 99,710 15,48 1.925,35 4.m.589
95.180 1,477.040 449,310 733.688 2.165,805 285,087 109,411 17,689 2.146,138 5.315.522
106595 15,573.692 4532.172 7.98.310 24.280,884 3.803,529 1,144,056 212,381 24.06503 58.38.238
(less)
Adlustments for Curtilments, Buy. Throuahs and Load No Lonoer Sered (Reductions to Load)
Non.FERC FERC -i
CA OR WA E.WY UT 10 W.WY UT NETUT Tot
(5.977 .(5.977 (5.977
-..-
...-
-(2).(28).(58).(58)
(5.66)(1.541)(5.869)11,210)
(6.68)(9,33)(6.68)(16.016)
11.54)(9,001)11.54)(16.54)
(4.33)(4.916)(4.33)(9.246)
-(4.55)-(4.55)
.(2.522)-(2.522)
(6.013);8.615)(6.013)(14.629)
---.36.215 /41,324)..36,215)17 ,539\--equals
I LOADS SERVED FROM COMPANY RESOURCES (NPC)
i Non.FERC FERC I
CA OR WA E.WY UT 10 W.WY UT NeIUT Tot
97,192 1.572.33 461.73 715.08 2,107,496 296,94 99.86 17.410 2.09.08 5,35.65
82.867 1,297.88 371.626 628.94 1.810,68 224,2 89.442 14.49 1,796.190 4.50.716
97.215 1.280.162 35.796 68.825 1.80,20 250,763 94.423 15.679 1,784.526 4.525.392
87.951 1.170,197 324,757 621,20 1.719.95 251,69 90.381 15.43 1.704.524 4.26,140
92.26 1.20,896 311,841 63,787 1.918.429 38,520 93,54 17.396 1.901,31 4.84.08
93.106 1.193.34 34.371 64,991 2,106.36 44.90 92,020 19,402 2.08.962 4.919,108
91.69 1.33.26 411.50 68.659 2,49.40 452.021 97,139 23,363 2.470.041 5,56,69
93.807 1.30.327 38.54 68.158 2.420.607 34.793 94,43 22.94 2.397.861 5.342.471
74.89 1.181.393 35.019 65.342 1.923.209 295.835 86.712 17,370 1.90.84 4,58,406
78.56 1,240,775 38.128 65.33 1.84,702 260.628 96,972 15,753 1.827.949 4.54,101
80.05 1.331,073 391.731 862.297 1.94,814 269.36 99,710 15.48 1.92,35 4.775,047
95.180 1.477,04 44,310 733,68 2.159,792 276.472 109,411 17,669 2.142,123 5,30.89
1.06,595 15.573,692 4.532.172 7.989,310 24,244,669 3,762,205 1144,056 212,381 24.032,289 58,310,699
+ plus
Adlustments for Ancillary Services Contrcts Includina Reseres (Additions to Load)
I Non-FERC FERC 1
CA OR WA E.WY UT 10 W.WY UT NetUT Tot
38 1,295 38 1.68
492 224 49 717
420 229 420 64
260 993 26 1.254
421 1.322 421 1.743
347 4.759 347 5.106
180 13,45 180 13.63
596 12.437 596 13,03
35 5.851 35 6.201
326 6.43 326 6.759
167 2.710 187 2.878
418 9,857 418 10.275
.-..4.36 59568 -.4,36 63.931
= equals
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (MWH) . Prior to temperature adjustment 1
I Nan-FERC FERC I
CA OR WA E.WY UT 10 W.WY UT UT Totl
97.192 1.572,33 461.738 715.080 2.107.681 30.23 99,86 17.410 2.09,471 5.35,33
62.867 1.297,88 371.26 628,94 1.811,181 224.491 89,42 14,496 1.796.682 4.50.432
97,215 1.26.162 35,796 66.825 1,80,627 250,99 94,423 15.679 1.784,94 4,526.042
87,951 1.170.197 324.757 621.206 1.720,218 252,68 90.381 15.433 1.704.785 4.267,394
92.263 1,20.89 311,641 63,787 1.918.65 38,842 93.54 17.396 1.901.452 4,647.824
93.106 1,193,34 34.371 64,991 2.106.711 45.667 92.020 19,402 2.087.30 4.924.214
91.69 1.33,260 411,50 68,659 2,49.583 46.479 97.139 23,38 2.470.221 5.576.328
93,607 1.30,327 38.54 68,158 2.421.20 381.23 94.43 22.94 2.39.257 5.35,50
74.896 1.181.393 35,019 65.342 1,923,58 301.68 86,712 17,370 1.90.190 4,574,607
78.582 1.240.775 38,128 659,33 1,84,028 267.061 96.972 15.753 1.628.275 4.55,86
80.05 1.331.073 391,731 662.297 1,94,961 272.074 99.710 15,48 1.92.521 4,777,925
95.180 1.477.04 449,310 733,68 2.160,210 286,329 109.411 17,669 2.142.541 5.311,169
106,595 15,573,692 4,532.172 7.989,31Q 24,249,033 3,821,773 1.144,056 212,381 24,036,652 58,374,631
ALOCTIONS USING HISTORICAL LOADS
FACTORS BAED ON DECEMBER 2007 HISTORIAL LOAD
Idaho Der 207 Genenl Rat Ca..
ENERGY
Yea Mo207 Jar7
2007 Feb720 Ma-0200 Al.o7207 May720'1 Ju7207 Jul7207 Ai7207 Se207 0c7
207 Nov.o7207 0e7
Ye¥ Mo207 Jar7207 Feb7
207 Mar.o720 Al.o7207 May7207 Jun7207 Jul7207 Ai7207 Sep7207 0c7207 N07207 0e7
Yea Ma'"207 Jan-7207 Feb7
2007 Mar.o7207 /l.o7207 Ma7
2007 Jun7207 Jul7207 Au7207 Se7207 0c7
2007 Nov.o72007 0e7
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (MWH) . Prior to temperature adjustment I
I NOn-FERC FERC 1
CA OR WA E.WY UT 10 W.WY UT UT Totl
97,192 1.572.33 461.738 715,08 2,107,881 30.239 99,86 17,410 2.09,471 5.35.33
82.86 1.29.88 371.626 628.94 1,811.181 224.491 89,442 14.498 1,796.682 4.50.43
97,215 1.60,162 353.798 86825 1,80.627 250.993 94.423 15,679 1.784.94 4.526.042
87,951 1.170.197 324.757 621.20 1.720.218 252.68 90.381 15.43 1,704.785 4.26.39
92,26 1.20,89 311.641 63,787 1,918.85 38.842 93.54 17.39 1.901.452 4,647,824
93.106 1.193.34 34.371 64,991 2.106,711 45.667 92.02 19.40 2.08,30 4,924.214
91,69 1,33,2 411.50 68,659 2.493.58 46.479 97.139 23.36 2.470.221 5,576.328
93.607 1,30,327 38.54 68.158 2,421,203 361.23 94.43 22.94 2.398,257 5,35.50
74,896 1.181.39 35.019 65.342 1.923.56 301,68 86.712 17.370 1.90.190 4.574.607
78,562 1,240.775 36,128 65.33 1.84.028 267,061 96.972 15,753 1.82,275 4,552.86
80,05 1.331.073 391,731 68.297 1,94.981 272.074 99.710 15.46 1.25,521 4,m.92
95.180 1.477,04 449.310 73,68 2,160.210 286.329 109.411 17,66 2.142,541 5,311.169
106.595 15,573,692 4.532.172 7,989310 24,249,033 3.821.773 1,144,05 212,381 24036,652 58374.631
(less)
Temiirature Adjustment for Enerov
I No-FERC FERC I
CA OR WA E.WY UT 10 W.WY UT NETUT Tola
(1,781)(14.48)(7.40)(3.576)(38.152)(4.903)(784)-(38.152)(71.083)
(327)3.403 (745)2,2 7.50 2,73 297 .7.503 14.68
751 21.36 2.531 5.59 12.574 2,53 44 -12.574 46.32
(183)(659)(4.155)(1,82)(8.517)15 115 .(8.517)(15.20)
(85)(11.30)(3.772)(2.522)(61.43)(2,66)(135)-(61.43)(82,88)
(342)(9,46)(88)(3,577 (85.55)(3.26)(252)-(85.55)(103.33)
(1.193)(24,707)(22,807)(5,579)(141.729)(4.182)(44)-(141.729)(20.63)
(113)(8,702)(2,623)(3.08)(101,45)(3.585)(251).(101.45)(119,818)
(419)(13.36)(4.624)(2.93)(40,93)(1.764)(128)-(40.93)(64,165)
53 4.247 (2.423)(1.357)(8.016)(842)(9).(8.016)(8.231)
84 9,721 (4.35)3.23 5.592 (80)23 .5.59 14.420
(46)13.496 3.756 (3.104)(10.682)874 (20).(10.682)4.089
438 129,986 147,496 16.448 1470,800 15,536 1,196 -1470,8001 f585,848l
equals
I NORMALIZED LOADS FOR JURISDICTIONAL ALLOCATION (MWH)1
i Non.FERC FERC -i
CA OR WA E.WY UT 10 W.WY UT NetUT Totl
95,412 1.557.85 45,33 711,50 2.06,729 295.33 99.08 17.410 2.05.319 .5,283.250
82.54 1,301.28 370,881 831.22 1,818,68 226,764 89,739 14.49 1.80.185 .4.521.115
97.96 1,281.99 35,329 674.424 1,813.201 253,5 94.867 15.679 1.797.522 .4.572.370
87.767 1,169.53 320.603 619.38 1,711,701 252.698 90.49 15.43 1.69.268 .4.252.187
91,413 1,195.587 307,870 63.265 1.857,420 38,973 93.40 17.398 1,84.022 -4.56.93
92,764 1,183,683 34,490 64.414 2,021.159 447,399 91.768 19,402 2,001,756 -4.820.876
90,50 1.30.55 38,702 678.08 2.351.85 461,97 96.697 23,36 2,328.492 -5,375.689
93,493 1,30.625 38.920 68.06 2.319.747 357,646 94.185 22.94 2.2.801 .5,235.686
74.477 1,168.033 351.395 647.40 1,682,625 299,922 86,585 17.370 1.865,255 .4,510.442
78.616 1,45,022 36.705 657.977 1.83.012 266,419 96.879 15.753 1.820.259 -4,54.629
80.123 1.34.794 387.378 66.53 1.94,574 271.995 99.94 15.46 1.931.113 .4.792.34
95.133 1490,53 45,06 730,584 2149,528 287,203 109,207 17,66 2.131,860 -5315.258
1,06,208 15,543,706 4,48,676 7,972,861 23,778,233 3,80,237 1,142,861 212,381 23.565,852 .57.788,783
Pag 10.16
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DECEBER 20 HISTORI LOADlcaho Demb 207 Ge Re Ca..
AN EMBEDDED COSTSoebe.Q7YE EN BA
C_pony Ow Hyro - westAcDepton Amount Mwh $I ~IRerence
53.54 Hy Opti & Maitenance Ex 23,175,922 Pag 2.7, West only
40P Hy Deti Exse 10.98.087 Pag 2.15, West onl
401P Hyd R_sin Amo 5.n9,525 Pag 2.16, Wet only
Totl we Hyro Operag Ex 31.868.513
33.33 Hy El Plnt in Se 44,48.642 Pag 2.23. we only
30& 182 Hy R_si 101.19,427 Pag 2.29. Wes only
108 Hy Acle De Res (195.789.914)Pa 2.36. we only
l111P Hy Rel Accle Re_(11,84.377 Pag 2.39, Wes only
154 Me end Supps (21.081)Pa 2.32, we only
we Hy Ne Rele Su 34.897.897f'te Ret 11.1lRe Be.. Revue Re 40.558
Anl Eibe_ Costwe il_ Reso 10,129,071 3.89.03 20.58 (112,142.820) MW!r GRID
MIcCC-.ct
Acount Dnrtpton Am Mw $lwh Dlntal Rerence
55 Anual MidC Cotr CoSIS 59,02.490 2,06,879 28.59 (42,95,242) GRIDGr Reasobl Po (790.311)(7.90.311) GRID
51.126.179 (50.855,553)
auFacHite.
Acco Depton Am Mwh $I DHrental Reerence
55 Ut Ann Qualif Facilis CoslS 26,682,50 400,60 66.61 6,897,205
55 Or Ann Qu F-' Co 41,43,241 345,547 119.82 24,3n,09
55 1_ An Qulfie Fii Co 4,101.55 77,028 53.25 297,230
55 W' Am Qulfie Faclis Co55WV AMUal Qualif Faclit Co 66.30 11,394 58.57 104,58
55 Cell Anal Qu6f Fii Co 4.09,824 35,50 115.43 2,44,53
55 W8 Ann Qualif Fii Cost 2,191.766 20,339 107.76 1.187.250 .Tot Qu F_s Co 79,179,310 19,414 68.92 35.2,90 GRID
AU Olr Gen Rerc
(Ex. Wes Hyd, MI C. an QF)
Acunt DeptIon Amnt Mw $lwh Rerence
50-514 St Opti & Maintenanc Exnse 88,802,654 Pa 2.5
53.545 Ea Hy 0p & Maan Exse 12,25,210 Pag 2.7, East on
54- 55 Ot Ge Opon & _ Exse 618,824,30 Pa 2.8
55 0I Pued Po Co 1,82,521,29 GRID ..IS QF and Mi
4010 R.. Eny Cre (48,019,89)Pag 2.20
4118 S0 Emss AlIs (3,153,48)Pag 2.4
Jam Riv I Ut Moun Of (7,377,175)Jer Riv Ac (Teb 5)
Gr Tag Revues (6.92,170)Gre Tag (Teb 3)
40P St De Ex..104.89,607 Pag 2.15
40P Ea Hy De Ex 4,215.72 Pag 2.15. Ea on40Ot Ge Deat Exnse 63.514,424 Pag 2.15
40P MI De Exnse 0 Pag 2.15
401P East Hyro Retcesin Amo 327,571 Pag 2.16. Ea on
40 Amo of Plan Acquisiton Costs 5.479,353 Pag 2.17
Tot AU Ot Operotiii Ex..s 3,45255.622
310- 316 St EI Plan in Se 5.08,202,38 Pag 2.21
33.33 Eas Hy EI Plan in Sece 112,749.38 Pag 2.23, Ea on
30& 186 Ea Hy Relicsin 9,641.735 Pag 2.29, Eat on
34.34 Ot EI Plnt in Se 2,00,478.50 Pa 2.24
399 MI 437,270,078 Pa 2.28
108 St Accmul Deprat Res (2,45072,136)Pa 2.36
108 Ot Geti Accmu Den Resee (126.33,401)Pa 2.36
108P 0I Acul Deat Re_(158,88,819)Pa 2.38, Ea on
l08HP Ea Hy Accmute Deprti Res (3.93,851)Pa 2.36, Ees on
l111P Ea Hy Rel Accte Rese (2,790,669)Pa 2.39. Ea on
114 EI Plnt Acqsi Adjust 157,193,780 Pag 2.31
115 Acc Prio Acqisit Adjst (8.38,167)Pag 2~31
151 Fue St 118,297,341 Pag 2.32
25.16- 25 19 Jo Ow we De (2,368,144)Pag 2.32
25398 S0 Em AlIces (40,728,101)Pag 2.34
154 Me & Suies 73,22.690 Pag 2.32
154 Ea Hy Maals & SupplsTot Ne Rele Ba..5.070.976.55
Pr Ret 11.82%
Ra Ba Reveue Reuire 59.241.58
Anl Embe Co
AU Ot Getion Rerc.4,053,497.201 82073.336 49.39 MW !r GRID
Totl Annual Embedded Costs 4,263,931.63 88.921,S61 47.95
Page 10.21
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_SfP 19 Al1lO: 52 ~:::~~~:~C-E-08-07
IDAHO PUBliC Exhibit No. 13
UrlLtTIES COMMISSION Witness: Brian S. Dickman
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Confidential
Exhibit Accompanying Direct Testimony of Brian S. Dickman
Chehalis Detail
September 2008
THIS EXHIBIT IS CONFIDENTIAL
AND IS PROVIDED UNDER
SEPARATE COVER