20210527Meredith Exhibit 48.pdf

CaseNo. PAC-E-21-07
ExhibitNo.48
Witness: Robert M. Meredith
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
ExhibitAccompanying Direct Testimony of Robert M. Meredith
Cost of Service Study
May 2O2l
Rocky Mountain Power
Exhibit No. 48 Page 1 ol 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
ROCKY MOUNTAIN POWER
COST OF SERVICE
FU NCTIONALIZATION, CLASS IF ICATION & ALLOCATION PROCEDU RES
INTRODUCTION
The Class Cost of Service Study is based on PacifiCorp's normalized results of operations.
It employs a three-step process referred to as functionalization, classification, and
allocation. These three steps recognize the way a utility provides electrical service and
assigns cost responsibility to the groups of customers for whom the costs are incurred.
Functionalization
Functionalization recognizes the different roles played by the various facilities in the
electric utility system. lt is the process of separating expenses and rate base items to
determine a separate revenue requirement for each of five major electric utility functions;
Production (or Generation), Transmission, Distribution (Potes and Wires), Retail Services
and Miscellaneous Services. These functions are also referred to as P, T, D (or DPW), R,
and M.
The production function consists of the costs associated with power generation, including
coal mining and wholesale purchases.
The transmission function includes the costs associated with the high voltage system
utilized for the bulk transmission of power from the generation source and interconnected
utilities to the load centers.
The distribution function includes the radial distribution system that connects the customer
to the transmission system. This includes distribution substations, poles and wires, line
transformers, service drops and meters.
The retail service function includes the retail activities associated with customer service
including meter reading, customer accounting, customer service activities and sales.
The misc. services function is a catchall for expenses that are associated with regulatory
activities. These activities include franchise requirements and regulatory commission
expenses.
Classification
Classification identifies the component of utility service being provided. The Company
provides and customers purchase service that includes at least three different
components: demand-related, energy-related, a nd customer-related.
Demand-related costs are incurred by the Company to meet the maximum demand
imposed on generating units, transmission lines, and distribution facilities. The maximum
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Rocky Mountain Power
Exhibit No. 48 Page 2 ot 171
Case No. PAC-E-21{7
Witness: Robert M. Meredith
demand influences the size of these facilities, and correspondingly, the amount of
Company investment and related expenses.
Energy-related costs vary with the output of a kWh of electricity. Typical energy-related
costs include fuel, maintenance that occurs on the generating unit due to running of the
unit, purchased energy and other costs that are impacted by the decision to supply energy
Customer-related costs are driven by the number of customers served. Once the
Company makes a commitment to serve a customer, these costs @ntinue, even if the
customer uses little or no electricity. At a minimum, they consist of the costs associated
with meters, service drops, meter reading, billing, and customer service related expenses.
Allocation
After the costs have been functionalized and classified, the next step is to allocate them
among the customer classes. Some utility plant and expenses can be identified as serving
one or a smal! group of customers and can be directly assigned to those customers. ln
most cases, however, utility plant and expenses are used to serve multiple classes of
customers. As such, those costs must be equitably shared among the customer classes.
This is achieved by the use of allocation factors, which specify each class' share of a
particular cost driver such as system peak demand, energy consumed, or number of
customers. The appropriate allocation factor is then applied to the respective cost element
to determine each class' share of cost. Factors with two digits (i.e. F30 - MWH) identiff
allocation factors that are calculated using cost driver information that is external to the
cost study.
Many expense and rate base items track plant investment or some other value in the cost
of service study. The allocation factors for these items are internally generated within the
cost of service model. lnternally identified factors are identified with three digits (i.e. F102
- Gross Plant). Many plant related allocation factors are identified by function and are so
identified (F102G - Generation Plant, F102T - Transmission Plant, F102D - Distribution
Plant and so on).
FU NCTIONALIZATION PROCEDU RES
For regulatory reporting purposes costs are collected into the Business Warehouse (BW)
database. Each account balance in BW is assigned a functional identification or FUNC
Factor. Account balances captured in BW that are directly related to one of the primary
business functions - P, T, D (or DPW), R, or M - are so designated. The functional
designation is generally driven by the location code associated Wth an asset or
transaction. !n some cases, the customer service system for example, the business
purpose of the asset or transaction is used rather than the physical location. Assets and
expenses that support more than one of the five (for example, administrative and general
expenses and generaloffice rate base) are apportioned between the functions. Those
items that are considered plant related are split between functions in the same proportion
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Rocky Mountain Power
Exhibit No.48 Page 3 ol 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
as generation, transmission, and distribution plant (PTD FUNC factor). Those items that
are considered directly related to employee compensation are split in the same proportion
as company labor (LABOR FUNC factor).
ln the Results of Operations Model (Jurisdictional Allocation Model or JAM), account
balances from BW are aggregated by FERC account and by 2020 Protocoljurisdictional
allocation factor and roll up to a single line item. Each of these line items is also assigned
or allocated to one or more of the functions using a series of functionalization factors
(FUNC factors). When all, or essentially all, of the account balance associated with one
FERC account and2020 Protocol factor have the same functional designation, that FUNC
factor is used. For example any item allocated to a jurisdiction using the SE factor is
generally fuel related and assigned to the generation function using the "P' FUNC factor.
When the various account balances from BW that roll up to one line in the JAM and have
more than one functional designation, a new FUNC factor is developed. An example of
this is the SCHMAT-SO FUNC factor. Of the Schedule M Additions Temporary account
balances allocated on the SO Protocolfactor, some are labor related, some are directly
associated with generation and some are overall plant related. Each of these account
balances is assigned or apportioned to the appropriate tunction. The SCHMAT-SO FUNC
factor is derived from the summation of the account balances by function. The Schedule
M Additions Temporary allocated to a state using the SO Protocol factor are then assigned
to tunctions using the SCHMAT-SO FUNC factor.
Some FUNC factors, such as the Production, Transmission and Distribution (PTD) factor
or the Cash Working Capital (CWC) factor are calculated from data inside the JAM model
Operation Revenues:
General Business Revenue: Account 44045. Residential Revenues, and Account 442,
Retail - Commercial and lndustrial Revenues, are not functionalized. The dollar amounts
assigned to PTDRM for retail revenues have been derived to produce the jurisdictional
normalized ROE.
lnterdepartmental: Account 448. lnterdepartmental Sales, is allocated to Distribution
Poles & Conductor (DPW).
Special Sales: Account 447. Firm Wholesale Sales (sometime referred to as Sales for
Resale), are allocated to Production "P".
Other Operating Revenue: Accounts 450 to 456. Other Revenues is functionalized on
the "OTHREV" factors. The vast majority of revenue in this line item is associated with
account 456 and has been functionalized using the "OTHSE" factor. These factors are
developed by identifying each specific revenue item as PTDRM.
Operating Expenses:
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Rocky Mountain Power
Exhibit No, 48 Page 4 ot '171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
Production: Accounts 500-557. Production expense includes allgeneration maintenance
expenses as well as fuel and purchased power expenses. All of these costs are assigned
to P.
Transmission: Accounts 560-573. Transmission costs, including wheeling expenses, are
assigned to T.
Distribution: Accounts 580-598. Maintenance and operation expenses are assigned to
D.
Customer Accounts & Sales: Accounts 901-916. Customer Accounts and Sales are
assigned to R.
Administrative & General: Accounts 920-935. Most A&G expenses are functionalized on
the 'PTD" functionalization factor. The "PTD' factor used here is based on the ratio of total
company plant investment between P, T & D. Costs that have been identified as
supporting customer systems are considered part of the retail function. Account 926,
Pension Benefits and Account 929 Duplicate Charges are functionalized on the "LABOR'
functionalization factor. The "LABOR" factor is based on the FERC Form 1 breakdown of
labor expenses between P, T, D & R (As shown above, Customer Accounting, Service and
Sales are considered part of the R function). Account927, Franchise Requirements, and
Account 928, Regulatory Commission Expense are assigned to M. Account 928, FERC
annua! charge is functionalized on the 'FERC" factor with the balance going to M. Account
935 is functionalized on the General Plant "G" factor.
Depreciation: Account 403. The functionalization of depreciation matches the
functionalization of rate base. For example, the functionalization of General Plant
Depreciation expense matches the functionalization of General Plant rate base.
Amortization: Accounts 404-407. Account 4O4, Amortization of Limited Term Electric
Plant is functionalized based on analysis of the items being amortized to this account with
the vast majority of the money being functionalized by PTD or CUST. Account 405, Other
Electric Plant Amortization is allocated on the "GP" factor. Account 406, Plant Acquisition
Adjustment Amortization and Account 407, Amortization of un-recovered Plant are
assigned to P.
Taxes Other Than lncome: Account 408. Property tax, Excise and Super-fund taxes are
functionalized to P, T, D, & R using the "GP" factor. The "GP" factor is different than the
'PTD'factor in that the .GP" includes Generaland lntangible plant balances in the
calculation.
lncome Taxes - Federal: The federal income tax calculations for PTDRM are based on
the functionalized breakdown of revenues and expenses as described above. ln addition
to the above expense deductions, Account 427,lnterest Expense, is functionalized to
PTDRM using the "GP" factor and deducted ftom PTDRM revenue. Schedule M Additions
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Rocky Mountain Power
Exhibit No. 48 Page 5 ot 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
and Deductions are functionalized and netted against PTDRM operating revenues to arrive
at totaltaxable income before state income tax.
Schedule M items that can be specifically identified with P, T, D or R are so assigned.
Those items that are salary or benefit related are functionalized using the "LABOR" factor.
Items associated with bond refinancing are functionalized using the "PTD" factor. The
reversal of book deprecation is functionalized according to book depreciation.
lncome Taxes - State: Account 409.1 1. The total income before state taxes is calculated
for PTDRM in the same manner as done for Federal income taxes. This amount is
multiplied by the composite state tax rate to arrive at functionalized state income taxes for
each function.
lncome Taxes Deferred - Net: Accounts 410 & 41 1. The Tax Department determines
whether the plant deferred income taxes are production, transmission, distribution or
general plant related. These items are functionalized into PTDRM accordingly, using the
"DITEXP" factor. Defened taxes associated with employee beneftts are functionalized
using the'LABOR" fastor. ltems associated with property taxes are functionalized using
the "GP" factor. ltems that can be directly associated with a function are directly
functionalized using "P" or'PT" factors.
lnvestment Tax Credit Adjustment: Accounts 411.40 & 411.41. The Federal deferred
investment tax credit was functionalized on the'PTD" factor.
Miscellaneous Revenue & Expense: Acmunts 41 1 .8, 421 & 431 .1. The gains and losses
arising from the sale of utility property are identified and assigned to P, T, or D. Emission
allowances are assigned to P. The interest expense associated with customer deposits in
Account 431.1 is assigned to R.
Rate Base:
Electric Plant in Service: Production plant rate base, Accounts 310 - 346, is assigned to
P. Likewise, transmission plant accounts are assigned to T. Distribution plant accounts
are split between D and R based upon asset utilization.
General and lntangible Plant: General plant rate base accounts, except coal mine plant,
which is assigned to P, are functionalized using functionalization factors. The General
Plant factors were developed using the functional identification in the Business Warehouse
reports of genera! plant. BW identifies investments by accounting location, as steam,
hydro, transmission, distribution, general office, or the customer service system. The
identified generation items are assigned to P and known transmission items are assigned
to T. General plant items that are assigned situs because they are associated with
distribution property are assigned to that function. The general office items within the BW
listing were functionalized on the "PTD'factor and those items associated with the
customer service system were functionalized to R. A separate General Plant
functionalization factor was developed to correspond to each PITA allocation factor.
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Rocky Mountain Power
Exhibit No. 48 Page 6 ot 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
lntangible plant was functionalized in the same manner
Plant Held for Future Use: BW tracks Account 105 transactions to production,
transmission, general and mining totals. Production and mining are assigned to P, and
transmission to T. The generalamount is functionalized using the "G" factor.
Deferred Debits: BW tracks and collects deferred debits that are related to production.
These costs are assigned to P directly. Situs and system overhead debits are
functionalized using the "DEFSG', 'DDSO2" and "DDSO6'functionalization factors. These
three factors were developed by generating a detailed listing of BW debits to situs and
system overhead.
Electric Plant Acquisition Adjustments: Account 114. All Electric Plant Acquisition
Adjustments are assigned to P.
Prepayments: Account 165. Situs prepayments for franchise taxes and regulatory
commission fees are assigned to R. Fuel related prepayments are assigned to P.
Property insurance was functionalized using .PTD". Other prepayments are functionalized
using the "PT" functionalization factor.
Fuel Stock: Account 151 assigned to P
Materials & Supplies: Accounts 154, 163 & 253.18. Materials and Supplies are
functionalized using the "MSS" factor. This functionalization factor was developed using
FERC form 1 data.
Working Capital: Accounts CWC, 131,135, 143, 232 & 253. Cash Working Capital is
calculated by subtracting the expense lag days from the revenue lead days and multiplying
this difference times the daily cost of service. The daily cost of service is calculated within
the model by adding 12 months of O&M, Taxes Other than lncome, and State and Federal
lncome Taxes and dividing by 365. This amount is functionalized using the "CWC" factor.
The 'CWC" factor is internally calculated by adding the O&M, Taxes Other than lncome,
and State and Federal lncome Taxes, for each of the three functions and dividing by the
functional total, (Production/Total, Transmission/Total, Distributionffotal).
Weatherization: Accounts 124, 182,186. Weatherization loans and other deferred debits
related to conservation and DSM programs are assigned to M.
Other Miscellaneous Rate Base: Accounts 182.22 & 141. Other miscellaneous rate
base includes the deferred debits related to the Trojan Nuclear Plant which are assigned to
P.
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Rocky Mountain Power
Exhibit No.48 Page 7 ol 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
Accumulated Provision for Depreciation & Amortization: Accounts 108 & 111. The
functionalization of the accumulated depreciation matches the functionalization of rate
base.
Accumulated Deferred lncome Taxes: Accounts 190,281-283. The largest component
of accumulated deferred income taxes is due to timing differences between book
depreciation and tax depreciation. This timing difference is functionalized on the
"ACCMDIT'factor. Detailto develop this factor is supplied by the Tax Department. The
percentage for P in the "ACCMDIT" factor, for example, is developed by taking the total of
production items as determined by the Tax Department and dividing it by the total of all
PTDRM items. This includes the accumulated deferred income taxes arising from general
plant wttich are functionalized using the "G' factor for the purposes of developing the
'ACCMDIT" factor.
Unamortized lnvestment Tax Credits: Account 255. The accumulated investment tax
credits are functionalized using the 'PTD" factor.
Customer Advances for Construction: Account 252. State situs customer advances for
construction are assigned to D. System allocated advances are assigned to T.
Customer Service Deposits: Account 253. Customer service deposits are assigned to R.
Other Miscellaneous Rate Base Deductions: Account228. All items are functionalized
using the "PTD" factor.
CLASSIFICATION AND ALLOCATION PROCEDURES
Generation and Transmission Costs
The methodology used in this study for the classification and allocation of generation and
transmission costs are consistent with the MSP 2020 Protocol method. The MSP 2020
Protocol identifies three categories of Resources: Regional Resources, State Resources,
and System Resources. Fuelcosts are classified as 10Oo/o energy related. Production
and transmission plant and non-fuel related expenses for all resources are classified as
7 5o/o demand-re lated and 25o/o e n e rg y-re lated.
Energy related costs are allocated using each class' share of annual MWH (F30)
Demand-related costs are allocated using each class' contribution to the 12 monthly peaks
coincident with the PacifiCorp system firm peak. Demand costs are allocated in this
manner because capacity is important to the Company each month for meeting peak
loads, load following, and accommodating plant maintenance. For these reasons, the
Company supports the use of all twelve monthly peak loads in the capacity allocation
factor (F12). The energy portion is allocated using class MWH adjusted for losses to
generation level (F30). The fixed costs composite factor is (F10).
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Rocky Mountain Power
Exhibit No. 48 Page 8 ot 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
The Embedded Cost Differentials are allocated using the generation fixed costs composite
factor (F10).
Transmission plant is classified and allocated using the same methods described for
generation resources.
Distribution Costs
All distribution costs are classified as either demand related or customer related. There
are no significant energy-related costs associated with the distribution system. ln this
study only meters and services are considered customer related with all other costs
considered demand related.
To understand how demand-related costs are treated it is first necessary to understand the
concept of diversity. Diversity is the characteristic whereby individual customer peak
demands usually occur at different times. Because of this, a piece of equipment, such as
a power plant or a substation, which is used by many customers, does not need to be
large enough to meet the sum of the individual customer peak demands (non-coincident or
billing demands). Rather it needs to be just large enough to meet the coincident peak
demand (demand that occurs at the same time) of those customers.
The demand-related costs fall into two subclassifications: those that vary with changes in
overall system load (system costs) and those that are established at the time customers
are connected to the distribution network and seldom vary after that time (facilities costs).
PacifiCorp's distribution system is primarily a set of radial lines extending from substations
connected to the transmission system. As you move through these radial branches, from
the substation to the meter, the number of customers using each piece of equipment
declines and, with that decline, the diversity in the load on each piece of equipment also
declines. While the transition between system costs and facilities costs occurs gradually
over the distribution system, it becomes necessary in a cost study to draw a line between
equipment which is judged to fit best into each of the categories.
Substations and Primary Lines
Distribution substations and primary lines fall into the system costs category. Because
many customers use substations and primary lines, an allocation methodology that
recognizes the diversity of load among the customers is used. Distribution substations and
primary lines are allocated using the weighted monthly coincident distribution peaks (F20).
The coincident distribution peak is the simultaneous combined demand of all distribution
voltage customers at the hour of the distribution system peak. These monthly values are
weighted by the capacity of substations that achieve their annual peak in each month of
the year.
Secondary Lines
Distribution secondary lines operate as an extension of the line transformer. They are
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Rocky Mountain Power
Exhibit No. 48 Page I ot'171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
allocated using the NCP method. Only customer classes where transformers are shared
by more than one customer are alloerted the costs of distribution secondary lines. (F22)
Services and Meters
Services costs are allocated to secondary voltage delivery customerc only. The allocation
factor is developed using the installed cost of newly installed services for different types of
customers. (F70)
Meter costs are allocated to all customers. The meter allocation factor is developed using
the installed costs of new metering equipment for different types of customers. (F60)
Line Transformers
Only customers taking service at secondary voltage are allocated distribution line
transformer costs. The allocation factor (F21\ is based on the installed cost of different
transformers used by each class. The calculation is done by matching customers to the
transformers used to serve them and then allocating the current cost of those transformers
to the customer's class. When a transformer is used by customers from multiple classes,
the portion of the transformer assigned to each class is determined by the class share of
NCP on each transformer. Line transformers are allocated to the street lighting class on
the basis of NCP.
Customer Accounting, Customer Services & Sales
Customer accounting, customer service, and sales expenses are considered customer-
related costs. They are allocated to customers using weighted customer factors. The
weightings reflect the resources required to perform such activities as meter reading,
billing, and collections for different types of customers.
The customer weightings for Meter Reading expenses, Account 902, are determined by
the typical time, including travel time between meters, to read meters for different classes
of customers. (F47)
The customer weighting for Customer Accounting and Records expenses, Account 903, is
a composite of the number of customers, customers receiving manual bills and the amount
of write-offs by customer class. (F48)
Uncollectible Accounts expense is allocated based on class net write off history. (F80)
Customer service expenses are allocated on number of customers (F40).
General & lntangible Plant, Administrative & General Expenses
Most general plant, intangible plant, and administrative and general expenses are
functionalized and allocated to classes based on generation, transmission, and distribution
plant (F102). Costs that have been identified as supporting customer systems are
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Rocky Mountain Power
Exhibit No. 48 Page 10 ol 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
considered part of the retail function and are allocated using customer factor (F42').
Regulatory Commission Expense is allocated on Revenue (F141).
Taxes
State and Federal lncome Taxes are allocated on Rate Base (F101). An embedded cost
of service study is designed to determine the revenues needed to provide an equal rate of
return for all classes. At full cost of service, allocating income taxes on rate base produces
the same result as allocating on income. This simplifies and reduces the size of the cost
model by eliminating the need to allocate all of the taxable income adjustments.
Deferred lncome Taxes are allocated primarily on Net Plant (F104). Most deferred taxes
are a result of plant investment. Deferred lncome Taxes associated with bad debt are
allocated using customer factors (F42). Defened lncome Taxes associated with employee
benefits are allocated using labor (F138).
Taxes Other Than lncome Taxes are allocated on Plant (F101). The bulk of taxes other
than lncome Taxes are property taxes. Property Taxes are assessed on plant investment.
Rate Base Additions and Deductions
Additions and deductions that relate to Generation and Transmission plant are allocated
accordingly (F10). ltems that are associated with Distribution plant are allocated in a
similar manner (F20). Items directly relating to fuel or coal mining are allocated on energy
(F30). Weatherization investments are allocated on (F40) consistent with customer
service expense. Accumulated Deferred lncome Taxes are allocated consistent with
Deferred lncome Tax Expense (F104). Customer advances for Construction are allocated
based on recent history for Contributions in Aid of Construction (F50). Where applicable,
Customer Deposits are allocated on recent deposit history (F51). All other additions and
deductions are allocated on Plant (F102).
Revenue Credits
ln the class COS study, no costs are assigned to wholesale transactions. The revenue
from these sales is treated as a revenue credit and is allocated to customer groups using
appropriate allocation factors. Other electric revenue is also treated as a revenue credit.
Revenue credits reduce the revenue requirement that is to be collected from firm retail
customers.
Sales for Resale revenue is classified between demand-related (F10) and energy-related
(F30). Other Electric Operating Revenue is assigned as closely as possible to the specific
customer classes providing the revenue.
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Rocky Mountain Power
Exhibit No. 48 Page 11 oI'171
Case No. PAC-E-21-07
\Mtness: Robert M. Meredith
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Exhibit No.48 Page 30 of 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
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Exhibit No. 48 Page 31 ot 171
Case No. PAC-E-21-07
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Exhibit No.48 Page 32ot 171
Gaee No. PAC-E-21{7
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Exhibit No.48 Page 33 of 171
Case No. PAC-E-21-07
Wtrese: Roberl M. Meredith
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Exhibit No. 48 Page * ot '171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
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Exhibit No.48 Fage 35 of '171
Caae tlo. PAC-E-21{7
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Exhhit No. 48 Page 36 of 171
Case No. PAGE-21-07
Witpss: Robeil M. Meredith
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CEs€ No. PAGE-21{7
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Carc No. PAGE-2!-07
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Exhibit No. 48 Page 39 of '171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
CUST DUSC Total
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19.U77%
0.00000/6
0.5863%
19.4159%
27.3U20h
0.00000/6
-0.25770h
27.3U2%
46.3243%
0.0000%
21.4595o/o
50.06630,6
'14.51480/0
0.0000o/5
70.7529%
49.8594%
0.00000/6
0.0000%
0.0000%
27.3U2%
17.41480h
49.8594%
0.064106
0.106506
0.00000/6
100.0000%
-1.8732%
0.00007o
11.0492o/o
0.000006
0.00000/6
0.0000%
0.0000o/5
0.0000%
0.0000%
1.32630h
0.00000/6
0.0000%
0.7093%
0.0000%
0.0000%
21.4194%
0.0000%
0.0000%
0.0000%
0.0000%
11.8485%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000Yo
0.0000%
0.00000/6
1.7693Yo
0.00000/6
5.U46o/o
5.6114%
1.7574%
0.70937o
0.0185%
0.95980/6
0.0(N60,6
12.2087%
-1.2482%
0.0000%
0.00000,6
-1.2528o/n
0.000006
0_0000%
4.06210/0
0.0000%
27.9291o/o
0.0000%
0.8601%
0.00000/o
5.9778%
0.0000%
7.8%4%
5.56460/6
0.00000/6
0.00000/6
0.0000%
0.00000/6
4.1231%
5.5il6o/o
0.0000%
0.00000/6
0.0000%
0.000OYo
-0.18050,6
0.0000%
0.82230h
1 00.0000%
0.0000%
100.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.00000,6
0.00000,6
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.00000/6
0.0000%
0.0000%
0.00000,6
0.0000%
0.0000%
4.2243%
100.0000%
0.0000%
-o.4119%
0.00000/6
0.0000%
0.00000/6
4.4131%
0.000006
0.0000%
0.0000%
0,00000,6
0.0000%
0.05510/6
0.000006
0.0000%
0.0553%
0.0000%
0.0000%
-0.0054%
0,0000%
0.0000oi6
0.00000/6
0.0000%
0.0000%
3.4124%
0.00000/6
3.9659%
2.79480h
0.00000/6
0.0000%
0.0000%
0 0000%
2_498704
2.7948o/o
100.0000%
100.0000%
0.00000/6
100.0000%
100.0000%
0.00000,6
100.0000%
100.00000/6
100.00000/5
100.0000%
100.00000,6
100.0000%
100.00000,6
100.0000%
100.0000%
100.00000,6
100.0000%
100.0000%
100.00000/6
100.0000%
100.0000%
100.0000%
'100.0000%
100.0000%
100.0000%
100.0000%
100.00000,6
100.0000%
100.0000%
100.00000/6
100.0000%
100.00000.6
100.000006
100 0000%
100.00000/6
100.0000%
100.0000%
100.0000%
100.0000%
0.0000%
100.0000%
100.0000%
100.0000%
100.0000%
100.000006
100.00000/6
100.0000%
0.0000%
100.00000,6
100.0000%
100.00000/0
100.0000%
100.0000%
100.0000%
100.0000%
100.00000/6
100.00000/6
100.000006
0.000006
100.0000%
100.0000%
0.00000/6
0.000006
100.000006
100.00000/6
100.00007o
100.000006
Deferred lnc,ome Tax
Book Depreciation
Communication Equipment Acct 397
Distribution Retail
Defened Debits - Situs
Defened Debits - Situs
Deferred Debits - System Overhead
Deferred Debits - System Overhead
Defened Debit - System Generalion
Distribution lvtscellaneous
Distribution Poles & Wires
Environmental Services Department
FERC FeeS
General Plant
General Plant - DGP Factor
G€neral Plant - DGU Factor
Total Plant
General Plant - SG Factor
General Plant - SITUS Factor
lntangible Plant
lntangible Plant - DGP Faotor
lntangible Plant - DGU Factor
lntangible Plant - SG Factor
lntangible PIant - SITUS Factor
Direct Labor Expense
Materials & supplies
Other Revenues - DGP Factor
Olher Revenues - DGU Factor
Other Revenues - SE Factor
Other Revenues - SG Factor
Other Revenues - Rolled-ln SG Factor
Other Revenues - SITUS
Other Revenues - SO Factor
Production
Schedule M Additions
Sohedule M Additions - Flow Through
Schedule M Additions - Permanent
Schedule M Additions - Permanent-So
Sohedule M Additions - Tempomry
Schedule M Additions - Temporary-GPS
Schedule M Additions - Temporary-SE
Schedule M Additions - Temporary-SITUS
Schedule M Addilions - Temporary-SNP
Schedule M Addiiions - Temporary-So
Schedule M Deductions
Schedule M Deductions - Flow Through
Schedule M Deductions - Permanent
Schedule M Deductions - Permanent- SO
Schedule M Deduclions - Temporary
Schedule M Deductions - Temporary-GPs
Schedule M Deduotions - Temporary-SG
Sohedule M Deductions - Temporary-SITUS
Schedule M Deductions - Temporary-SNP
Schedule M Deductions - Temporary-So
Transmission
Tax Depreciation
Transmission / Distribution
Cash Working Capital
Defened lncome Tax - Expense
Federal lncome Taxes
lncome Before Taxes
Not Functionalized
Non-Utility
Produclion / Transmission
Prod, Trans, Dist Plant
Revenue Requirement
State lncome Taxes
Total
Total
100.0000o/o
99,694,571
Pro
36.3680o/o
Tm
27.3O72Vo
Dis
27.64300/o
PacifiCorp
12 Months Ended December 2020
Tax Depreciation
Rocky Mountain Power
Exhibit No.48 Page 40 of 171
Case No. PAC-E-2'|-OT
Witness: Robert M. Meredith
General
Retail
8-68189o
Production Transmassion Distribution
Total
Conversion to COS Functions
Percent of GenPlant in Functions
Allocation of GenPlant to Functions
Assignment of Mining to Prod Function
Misc
0.00000/6
36,256,969 27,223,797 27,558,558 8.655,247
Adjusted Totals 1,006,328,033 fi2,427,791 198,892,191 215,952,804 8,655,247
TA)(DEPR FACTOR 100.0000o/c 57.9163%19.76420/o 21.4595'/o 0.8601%o.oooo%
12 lllonths Ended December 2020
Gross Plant
$nNO's)
Rocky Mountain Power
Exhibit No. 48 Page 41 ot 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
Alloc.
Description Factor Funct. Amount Production Transmisssion DPW CUSTOITIER DMISG
Production Plant
Transmission Plant
Distribution Plant
Mining
General Plant
Business Centers
Utah Mine
Gen6ral Plant
General Plant
General Plant
Total General Plant
P
T
DPW
P
CUST
P
P
T
DPW
DPW
P
DPW
P
TD
SE
CN
SE
SG
SG
SO
SSGCT
SSGCT
SITUS
SITUS
SITUS
12,652,733
7,627,713
7,647.962
90,658
17,295
5,130
128,315
179,088
0
0
0
260,492
0
423,U4
0
5,130
128,315
0
0
0
0
0
0
0
0
0
7,647,962
0
0
0
0
0
0
0
0
260,492
0
211,953
71,6277
733
0
0
2,652,0
3
0
0
0
0
0
0
7,295
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
90,658
0
0
0
179,088
0
0
0
0
0
21 1,391
1,013,663
195,355I
132,982
70,955
177,567
9,056
31,887
303,069
42,2't3
0
(15,518)
390,479 472,44 17,295't33,444
lntangible Plant
Cuslomer Service Sys
Customer Service Sys
Washington Hydro
Utah Hydro
Colorado Steam-UPD
Oregon Trans
Utah Mine
Utah
Utah G/O
Utah G/O
CUST
P
P
T
P
P
P
PTO
TD
LABOR
TD
CN
SE
SG
SG
SG-P
SG-U
SO
SO
SO
SO
SITUS
0
o
132,982
0
177,567
9,056
31,887
't37,303
0
0
0
0
0
0
70,955
0
0
0
42,773
21,O78
0
0,749\
0
0
0
0
0
0
0
82,993
2't,134
0
(7.769)
195,355 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Total lntangible Plant
Total Gross Plant
u7,574 488,803 167,058 96,358 195,355
29,980,302 13,365,
0
Func{ional Allocators:
P
T
TD
CUST
DPW
PTD
LABOR
'100.0000%
100.00000/6
100.00000/6
100.000070
100.00007o
100.0000%
100.fi)000/o
Prod
100.0000o/o
0.0000o/o
0.0000o/o
0.0000o/o
0.00000/6
45.3042o/o
43.5484o/o
Trans
0.0000%
100.0000%
49.9337o/o
0.0000%
0.000006
27.3117%
8.6542Vo
DPW
0.00000/6
0.00007o
50.0663Yo
0.0000o/o
100.0000o/o
27.3*2o/o
35.9489%
CUST
0.00000/6
0.0000Yo
0.0000o/o
100.0000%
0.00000/6
0.00000/6
11.8485Yo
DMISC
0.0000%
0.0000%
0.00(X)%
0.0fi)070
0.00000/6
0.00000/6
0.00000/6
Factor Total Produc{lon
PaclllCorp
12 iionths Ended December 2018
FERC FORii I Funtlonalizatlon Factors
Tran3mission
Rocky Mountiain Power
Exhibit No.48 Page 42ot'171
Case No. PAC-E-21{7
Witness: Robert M. Meredith
cusTDPW DMSC
IT
.LASSIFIED PLANT
TOTAL PLANT
27,928,407
0
27,928,407
12,652,733
12,652,733
7,627,713
7,627,713
7,647,962
7,647,1 62
0
0
0
0
0
0
o/oPLANT
P
T
DPW
PTD
PT
TD
100.00trt06 100.0000%100.0000% 100.0000Yo
100.00(x)%100.0000% 45.3u2% 27.31170100.0000% 62.38E8To 37.61'120/0100.0000% 49.93370h
',00.0000%
27.3842%
50.066306
0.0000Yo 0.0000%
LABOR
LABOR %
323,479,079 1'10,869,976 27.994.491 1 16,287,046 38,327,566
llatedal E Supplle3
Material & Supplies %
83,272j38 68,021,729 1,231,929 14,0't8.480 0
100.fiD0% 81.686t% 1.47%oh 16.8345%0.00@%0.0000%
FERC (MWh)28,123,308 1t,306,391 16,816,917 00
FERC %
Function
CUST
DPW
P
PTD
T
Book Depreciation
BookDepr Factor
Amount
957
168,914
597,409
't5,283
't 16,316
898,879
100.000/0
100.0000%
100.0000%
100.0000%
100.0000%
100.00c[,%
100.00007o
100.0000%
597,409
6.924
604.333
67.2318o/o
100.0000%
0.0000%
0.0000%
0.(x)00%
45.3M2Vo
0.0000%
20.3216Yo
4,174
1't6,316
120,490
13.i00,t6%
0.00000/6
100.0000%
0.0000%
0.0000%
27.31'.17Vo
49.9337%
36.02537o
DPW
16E,914
+,ias
173,099
19.257?/c
0.0000%
0.0000%
100.00000/6
0.0000%
27.3U2%
50.06630/6
42.3269%
PaciftCorp
12 Months Ended December 2020
Deprcciation Expense
Production Transmission
Rocky Mountain Power
Exhibit No.48 Page 43 of '171
Case No. PAC-E-21-07
Wtness: Roberl M. Meredith
cusT DMSC
957
0.t085%0.0000%
957
P
T
DPW
CUST
PTD
TD
o.0000%
0.0000%
0.0000%
100.00000/6
0.0000%
0.0000%
't.32630/o
0.0000%
0.0000%
0.00@%
0.0000%
0.0000%
0.0000%
0.0000%
Main
Account Factor Function Amount Produstion Transmission DPW CustomEr DMSC456OTHERP(12,919)-12,9190000456 OTHER T456 SE P456 SE T456 SG P456 SG T456 SO DMSC456 SITUS DMSC456 SITUS P456 SITUS T
Total Sifus Revenues
Total CN Revenues
Total SE Revenues
Total SG Ravenues
Total SO Revenues
Total Operation
oTl{slTus
CN Factor
oTl{sE
OTHSG
OTHSO
Total Operation Factor
o
0
(18,173)
(24,970)
(93,968)
0
(1,054)
(ee)
(23,7881
-24,940
0
-18,173
-l 18,957
0
-174,990
t00.0000%
0.0000%
100.0000%
100.0000%
#Dtv/o!
100.0000%
Total
100.00o/o
100.00%
,00.000/6
100.000/6
100.000/6
't00.009o
'100.000/6
PacifiCorp
12 Months Ended December 2020
Account 456
Rocky Mountain Power
Exhibit No. 48 Page M ol 17'l
Case No. PAC-E-2'|-07
Wtness: Robert M. Meredith
0.0000%
0.0000%
#Dtv/ot
0.0000%
0.0000%
20.9904%
#Dtvr0!
21.70870/0
0
0
0
-24,970
0
0
0
-99
0
-oo
0
0
-24,970
0
-37,988
0.39770/"
Prod
100.00%
0,00Yo
0.0070
0.00Yo
0.00%
45.30o/o
0.0070
0
0
-18,173
0
-9s,988
0
0
0
-23,788
-23,788
0
-18,173
-93,988
0
-1 35,948
95.3780%
Trans
0.00%
100.0006
49.93Yo
0.00%
0.00%
27.31o/o
0.00o/o
100.0000%
79.0096%
#Dtv/o!
77.68920/0
0.0000%
0.0000%
#Dtv/ot
0.0000%
0.0000%
0.0000%
#Drv/ot
0.80210/0
0
0
0
0
0
0
-1,054
0
0
-1,054
0
0
0
0
-1,054
4.22130/"
OMSC
0.000/6
0.000,6
0.00%
0.0004
0.00o/o
0.0070
100.00%
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0000%0.0000%
P
T
TD
CUST
DPW
PTD
DMSC
DPW
0.00%
0-00%
50.o70/o
0.00o/o
100.00%
27.38o/o
0.00o/o
CUST
0.00Yo
0.00%
0.009o
't00.0090
0.00%
0.00o/o
0.00%
BASED ON TOTAL COMPANY DATA
Alloc.
Factor Funct.
PacifiCorp
12 lt/lonths Ended December 202A
General Plant
Amount Prod
Rocky Mountain Power
Exhibit No. 48 Page 45 ot'171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
DPW cusTTrans DMSCDescription
Business Centers
General Plant
CN CUST 17,295
5,1 30
128,315
179.088
0
0
290,393
0
0
0 0 0 17,295
SEP 128,315 0 0SG
SG
SG
SO
SO
SO
P
T
TD
0 179,088eq.00
79,31 1
0
U
0
0
0
0
0
0
0
0
0
0
0
0
00000o -- o-- -o-- - -'-o-
0
0
SO DPW
TD
P
PTD 131 ,560
0
0
0
79,522
0
SSGCH PSSGCT DPWSSGCT P
SITUS
SITUS
SITUS
DPW
0
0
0
260,492
0
423,344
17,295
423,344
290,393
260,492
0
0
307,403
5,1 30
683,836
290,393
0
0
0
0
0
0
0
0
0
0
0
0
0
260,492
0
211,953
79,522
260,492
0
0
0
0
472,444
79,522
0
0
0
0P
TD 0 0 0 17,295 0Total4UST
Total-TD
Total-PTD
Total-DPW
To(al-SSGCH
Total.SSGCT
Total-G-SG
Total-SE
Total-G-Situs
Total-SO
0
131,560
0
0
0
128,315
5,130
0
131,560
211,391
79,31 '1
0
0
0
179,088
0
211,391
79,311
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Total-General Plant
G€G Factor
G-SlTuS Factor
SO Factor
G Allocator
Total Gen. Plant
Mining
Total
1,304,056 265,005 459,790 551,966
0.0000%
0.0000%
69-O874o/o
27.38420/"
4232A9y"
0.0000%
0.0000%
0.0000%
0.0000%
1.32630/o
0
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
,2957
,t00.00%
{00.00%
{ 00.00o/o
{00.00%
100.00%
1,304,056
90,658
1,394,714
41.74180/0
100.0000%
0.0000o/o
45.30420/0
20.32160/0
5,130
58.2584%
0.0000%
30.9'.1260/"
27.3117%
36.0253%
95,787acct 399 fron
P
Functional Allocators:P 100.00o/oT 100.00o/o
TD 100.00%cusT 100.00%DPW 100.00%PTD 100.00%GP 100_00%
Prod DPW
0.00%
0.00o/o
50.07olo
0.00o/o
100.00%
27.38o/o
27.41o/o
100.00%
0.00olo
0.007o
0.007o
0.00o/o
45.3Oo/o
44.584/o
Trans
0.00o/o
100.00%
49.93o/o
0.000/6
0.00o/o
27.31o/o
27.30o/o
CUST
0.00o/o
0.000/o
0.00o/o
100.00o/o
0.009o
0.OOo/o
0.71o/o
DMISC
0.00Y0
0.00o/o
0.00o/o
0.00o/o
0.00o/o
0.00o/o
0.00%
PacifiCorp
12 lionths Ended December 2020
lntangible Plant(n 000 s)
Alloc.Factor Funct" Amount Produclion Transmisssbn DPW Customer DMSC
Rocky Mountain Power
Exhibit No.48 Page 46 of 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
216,059
0.0000%
0.00007o
21.1191%
CUST
;EPSGPSGTSG-P PSG-U PSO CUSTSO DPWSOPSO PTDsoTSO TDSO LABORSO DMSCSITUS DPWSITUS PSITUS PTDSITUS TSITUS TD
Total.I)GP
Total.I)GU
Total€G
Total-SITUS
Total{ntengible
I€G FACTOR
l€itus FACTOR
! FACTOR
9
132,982
70,95s
177,fi7
9,056
20,7M
32,715
31.887
303,069
't,240
42,213
6,317
(15,518)
390,559
(e,044)
1,008,707
100.00%
100.00%
100.00o/.
100.00o/o
100.00%
100.00%
'to0.00%
100.00Yo
100.00%
100.007o
100.00%
9
132,982
0
177,567
9,056
0
0
31,887
137,303
0
0
0
0
0
0
0
0
0
319,605
488,803
81.8325%
0.0000%
48.681o/"
100.00%
0.00016
0.00%
0.000/6
0.00Yo
45.30Yo
0.00%
43.557o
82,773
1,240
21,078
0
0
0
0
0
6,3r7
(7,749)
70,9s5
11,432)
174,614
18.16750h
,15.8327%
17.31O7o1"
Els
0.007o
100.00%
49.93%
0.000,6
0.000/6
27.31o/o
0.00%
8.65%
(7,612)
129,230
0.0000%
81.1673o/o
12.8116o/n
DPW
0.00%
0.000/6
*.o70h
0.000/6
100.000/6
27.38o/o
0.000/6
35.95%
32,
0
0
70,955
0
0
0
0
0
82,993
0
21,1U
0
0
158
0
0
0
(7,76s)
158
0
0
0
0
0
0
0
0
15
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
20,7M
7 0
0
0
0
0
0
0
0
0
0
0
0
0.0000yo
0.0000%
0.(X}fit70
ProdFunctional Albcators:
0.00%
0.000/6
0.000/6
100.00%
0.00%
0.00%
0.000/6f .45%
DMSC
0.009o
0.00%
0.00%
0.00%
0.00%
0.00%
100.00%
0.0006
P
T
TD
CUST
DPW
PTD
DMSC
IABOR
Primary
Account
PITA
Factor Function
PaciffCorp
12 Momhs Ended December 2020
Schedule M
Amount Production Trensmisslon
Rocky Mountain Power
Exhibit No. 48 Page 47 ot 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
Poles I Wirs CBtomrB llriscellamus
ADDITIONS
SCHMAP-SCHMDEXP SCHMAPSCHMAP.SE SCHMAPSCHMAP.SO SCHMAPSCHMAP.SO SCHMAPSCHMAP-SO SCHMAP
LABORSHMDEXP
TABOR
SE
SO
so
so
P
P
172
45
1,743
1,568
3,311
3,528
100.00%
100.00%
109,924
9,5@
1,160,555
(6,s10)
64
40,983
2.745
582
88,441
3,814
2,48
2,545
73.1651'fo
72.153$Vo
517,392
(2,w2)
28
40,983
2.745
0
40,008
11,7U
(3€1)
(19,505)
(1.377)
(103,5r9)
(s2)
37
1,588
44,990
(1,31s)
(2,902)
41,011
40,327
45,87
11,403
530,819
&.5a11%
99.9'r8%
/15.2094%
100.59t2%
'lit.491t0%u.131t%
533,304
u-2133%
15
138
4.2589%
316,856(,7n1
8
159
24,1U5
2,338
(218)
(1
',945)
@2,;07\
12
316
desr
(1,7T1)I
24,314(/47)
2,1N
260,699
27.3/!2t to
0.0135%
273116|L
-t.0!173%
E.(ts70%
xxTayo
m6,850
a2.12fi%
a2
584
564
626
17.0250%
17.1328./o
109,924
318,076
(1,784)
23
100
24,215
3,814
9,7't1
(218)
(1 1,99r)
142,5721
20
186
186
206
5.6111%
5.84e/o
9,500
8,232
(40)
8
3.201
(3r0)
112
toul
8
4
432
3,201
21,138
0.7093%
0.01E5%
0.0046%
0.859E%
1L2W7%
1.7;71.4
0.0000%
0.0000%
(4,960)
(4,969)
0.0000%
0.0000?5
0.0000%
0.0000%
0.0@0%
4.41910h
75
45
1,743
883
PTD
SCHMAT-CIAC
SCHMAT.BAODEBT
SCHMAT.SCHMDEXP
SCHMAT€PS
SCHMAT.SE
SCHMAT.SE
SCH['AT.SG
SCHMAT.SG
SCHMAT.SG
SCHMAT.SGCT
SCHMAT€NP
SCHMAT.SNP
SHMAT.SNPD
SCHMAT-sO
SCHMAT-SO
SCHMAT.SO
SCHMAT.OTHER
SCHMAT-OTHER
SCHMAT-OTHER
SCHMATOTHER
SCHMAT.OIHER
SCHMAT-TROJO
SCHMAT.SITUS
SCHMAT.SITUS
SCHMAT.SITUS
SCHTVIAT€ITUS
SCHMAT€]TUS
SCHMAT-SITUS
SCHMATSITUS
SCHIvIAT-SITUS
Toral-so
TOTAI SCHMAP
scfltiAP€o
SCHMAP FACTOR
SCHMAT CIACSCHMAT BAODEBTSCHMAT SCHMDEXPSCHMAT GPSSCHMAT SESCHMAT SESCHMAT SGSCHMAT SGSCHMAT SGSCHMAT SGCTSCHMAT SNPSCHMAT SNPSCHMAT SNPDSCHMAT SOSCHMAT SOSCHMAT SOSCHMAT OTHERSCHMAT OTHERSCHMAT OTHERSCHMAT OTHERSCHUIAT OTHERSCHMAT TROJDSCHMAT SITUSSCHMAT SITUSSCHMAT SITUSSCHMAT SITUSSCHMAT SMJSSCHMAT SITUSSCHMAT SITUSSCHMAT SIIUS
Tolrl-GPS
Total€E
Total-SNP
TotalslTus
Total€o
TOIAI.SCHMAT
SCHI{AT€PS
SCHTAT-SE
scHtAT-stlP
scHrrtAT-smJs
SCHMAT-SO
SCHiIIAT FACTOR
SCHMAF DGPSCHMAF TROJP
Total€CHIIIAF
SCHiIAF FACTOR
136
151
4.0085%
DPVV
CUST
GP
GP
TABOR
P
DPW
P
T
P
GP
PTD
DPW
DMSC
TABOR
PTD
OMSC
GP
P
PTD
CUST
P
oMsc
DPW
ESD
GP
LABOR
P
PTD
T
4
3,648
44,e*
(2.911)
27.O13
(7s7)
(4,90e)
(/l{},751)(3nl
(228,498)
112
(s2)
(819)
12.
(8'r9)
73
'l.3ll
rintt
(r,784)
23
24,379
(23i )
9.493
389,129
27.472yo
0.0562%
2f .u130h
{.5t37%
*.,o920/"
32.3/516o/c
432
(6,510)
41,47
89,024
45.031
28,216
't,202,814
l@.00%
tqr.00%
t00.00%
r@.00%
r00.00%
r00.00%
SCHMAF.DGP
SCHMAF.TROJP
P
P
Total-SCH[iA
SCHMA FACTOR
O.OO.rC
1,2W,U4
t00.00./.
389,755
32.3087%
21,W
1.7@3%
(4,969){.itlt9%
SCHMDP.SCHMDEXPSCHMDP SCHMDEXP LABORSCHMDP-SE SCHMOP SE P
SCHMDP-SG SCHMOP SG PSCHMDP€NP SCHMDP SNP PTD
SCHMDP.SO SCHMDP SO LAEOR
SCHMDP.SITUS SCHMDP SITUS PTD
Total-so
Total-scHlllDP
SCHMDP-sO
SCHMOP FACIOR
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMOT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMDT
SCHMOT
SCHMDT
SCHMDT
SCHMDT
$CHMDT
SCHMOT
SCHMOT
SCHMDT
BADDEBT
CN
GPS
GPS
GPS
SG
SG
SE
SNPD
SNPD
SNP
so
so
so
SO
OTHER
OTHER
OTHER
OTHER
OTHER
OTHER
OTHER
OTHER
OTHER
TAXDEPR
SITUS
SITUS
SITUS
SITUS
SITUS
SITUS
CUST
CUST
GP
P
PTD
P
T
P
DPW
P
PID
ESD
GP
LABOR
PTO
CUST
DD52
DMSC
DPW
LABOR
P
PT
PTO
GP
TAXDEPR
DMSC
DDS2
GP
LABOR
P
2@,924
167,081
1,472
1,254
40
1,212
145,969
3.673
7,4O7
(219376)
1 15,084
18
(1241
765
DEDUCTIONS
4.933
on
4,982
98.E289p/o
93,745
167,08r
1,254
1,212
06,130
1. t02
3,481
(95,578)
52,r38
(1 18)
212
(25,841)
7,523
(4,979)
576,662
(610)
84
29
0.s&a%
56,514
1,472
39,867
367
2,132
(18,994)
31,431
(2)
4,77A
(3,049)
'196,788
4,933
108
5,041
0.a0%
100.0{r%
486
(2s,841)
17.488
(1 1,167)
995,682
(644)
189
Rocky Mouniain Power
Exhibit No. 48 Page 48 ot 171
- Case No. PAC-E-21-07
Witness: Robert M. Meredith
30
0.5863%0.0000%0.00@%
56,@t
40
39,972
2,2U
2,140
(78,899)
31,515
(8)
175
4,749
(3,061 )
213,068
(3e)
52
30
SCHMDT.BADDEBT
SCHMDT.CN
SCHMDT.GPS
SCHMDT.GPS
SCHMOT.GPS
SCHMDT.SG
SCHMDT-SG
SCHMDT.SE
SCHMDT-SNPD
SCHMDT.SNPD
SCHMOT-SNP
SCHMDT.SO
SCHMDT-SO
SCHMDT-SO
SCHMDT-SO
SCHMDT.OTHER
SCHMDT-OTHER
SCHMOT-OTHER
SCHMOT.OTHER
SCHMOT.OTHER
SCHMDT.OTHER
SCHMDT.OTHER
SCHMOT.OTHER
SCHMDT.OTHER
SCHMDT.TAXOEPR
SCHMDT.SITUS
SCHMDT.SITUS
SCHMDT.SITUS
SCHMDT.SITUS
SCHMBT.SITUS
SCHMOT.SITUS
55
(20,005)
18
58
(7s)
8,564
0
765
12
1
(8)
52
{21,2OA)(21,2ffi1
Total€N
Total€G
Tohl.sE
Total€l'lP
Total so
TOTAI OTHER
ToTaI TAXDEPR
TotalslTUs
Total SCHIIIOT
SCHI,IDT4PS
SCHMOT4N
SCHMOT.SG
SCHMDT.SE
SCHMDTSI{P
SCHMDT-SO
SCHti|oToTHER
SCHMDT.TA)(DEPR
scHiioT-slTUs
SCH,IIDT FACTOR
168,553
1,29
145,969
(92,912)
(18,374)
995,682
(2r,565)
'1.386,782
100.00%
0.00%
100.0,0%
100,00%
{00.0002
100.00%
't00.00%
100.0004
t0{r.00%
'100-firr/6
167,081't,zil
66,1 30
(38,858)
(22,8O2)
576,662
(21,722')
822,702
45.1U20h
39.887
14,936
1,768
196,788
86
311,431
27.3111%
1 A72
31 1,400
at37lryo
39,972
(43,041)
1,896
213,668
56
245,2*
27.3a420/"
0.0000%
0.0000%
27.W2%
s.3213%
-10.31720h
21.4595%
4.25n%
19./tl59%
249,285
19.{7f%
(2s,949)
('r)
8,564
IJ
(17,373t
0.00000/"
765
1
747
0.0000%
SCHMDF.DGP SCHMDF DGP
TOTAISCHMDF
scHttiloF FAcToR
P
99..t269%
100.00(x,%
#.truz.h
11.4225o/o
124.1@*/"
57.9{63%
100.7xt7./"
59-324li,/"
827,6U
5!r.{576%
0.E751%
0.000095
27.r117yo
-16.0759%
-9.6220%
19.lil2yo
{.3985%
22.157104
0.00007c
0.0000%
0.0000%
27.9291%
0.00,07%
0.860t%
4.0E,21%
-1.25280h
0.0000%
-1.8732%
100.0000%
0.0000%
0.70s3%
11.8485%
0.0000%
0.0000%
0.@00%
0.0000%
0.8601%
0.00@%
0.0000%
0.0000%
0.0@0%
0.0000%
4.1856%
0.0000%
4.0054%
0.05tt1|%
TOTAI-SCHMD
SCHiID FACTOR
0.000/"
1,3S1,823
r00_00%
t{et SCHiI
(17,373)
-1.21,2.h
747
0.0551%
&les3-@ CuslomsE !@]b!eggg0.0000% 100.0000%OMSC
DPW
DDS2
CUST
ESO
GP
LABOR
P
PT
PTO
T
TAXDEPR
TD
Ie!e[
100.00%
100.00%
100.00%
100.0@6
100.00%
100.00%
100.00%
100.00%
100 00%
1@.00Y0
1@.00%
100.00%
r@.00%
@
0.0000%
0.0000%
94;t415%
0.0000%
30.0@0%
44.5814%
43.5484%
100.0000%
62.3888%
45.3M2%
0.0000%
57.9163%
0.ofiD%
TEnsmission
0.00000,6
0.0000%
127M%
0.0000%
10.0000%
27.3021%
8.8*2%
o.0000%
37.611?!/o
27.3117
100.0000%
19.74420&
49.93370,6
0.0000%
't00.000006
6.0378%
0.000096
60.000096
27.4072%
35.9489%
0.0000%
0.0000%
27.38r'.2%
0.0000%
21.4555&
50.0663%
0.0000%
-0.1805%
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.00000/6
0.0000%
0.0000%
0.0000%
0.0000%
Paclflcorp
12 Months Ended December 2020
Reg Assets / Deferred Deblts
Rocky Mountain Power
Exhibit No. 48 Page 49 ol 171
Case No. PAC-E-21-07
Wtness: Robert M. Meredith
Prl.Acct Factor Function Total Production Transmlssion DPW CUST DMSC182MSEP193,842193,8420000RA.SE
RA.SG
RA.SGCT
RA.SG.P
RA.SO
RA-SO
RA-SO
RA.SO
RA.SO
RA-OTHER
RA.OTHER
RA-OTHER
RA-OTHER
RA-OTHER
RA-OTHER
RA.OTHER
RA.TROJD
RA.TROJP
RA.SITUS
RA.SITUS
RA.SITUS
RA.SITUS
RA.SITUS
RA.SITUS
P
P
P
DMSC
LABOR
ESD
P
TD
CUST
DMSC
LABOR
P
DPW
PTD
ESD
P
P
DMSC
LABOR
P
PTD
ESD
CUST
3,449
0
0
3,857
435,8114
29,371
0
0
238,912
4,810
't3,745
1',t6,924
0
4,633
0
0
0
103
(5,766)
(51,041)
0
(2,307)
1,756
469,073
379,024
(57,2s5)
988,133
100.00%
100.00%
3,449
0
0
0
189,803
8,811
0
0
0
0
5,986
1 16,924
0
2,099
0
0
0
0
-2,511
-51,041
0
-692
0
198,615
125,008
(il,244\
466,669
12.3119o/o
It1.7115%
0
0
0
0
37,719
2,937
0
0
0
8,280
31
8,280
0
0
0
156,681
17,623
0
0
0
0
0
0
0
51,641
0
0
0
234,9't2
0
.1,629
0
0
0
0
0
0
0
-683
0
0
0
1,756
51,641
240,540
1,073
293,254
u.ooe?/a
-1.8732%
0
0
0
3,857
0
0
0
0
0
4,810
0
0
0
0
0
0
0
103
0
0
0
0
0
3,857
4,810
103
8,771
0,8223r/o
{.1805%
182M SG182M SGCT182M SG.P182M SO182M SO182M SO182M 80182M SO182M OTHER182M OTHER182M OTHER182M OTHER182M OTHER182M OTHER182M OTHER,182M TROJD182M TROJP182M SITUS182M SITUS182M SITUS182M SITUS1A2M SITUS
182M SITUS
Total.SO
TotaIOTHER
Total SITUS
Total RA
DDSO2 FACTOR
DDS2 FAGTOR
1,190
0
0
1,265
0
0
0
0
-499
0
0
-231
0
40,656
2,455
(730)
42,38'.1
8.6673%
1.27440/o
4,94'.1
0
0
1,269
0
0
0
0
-2,073
0
0
-1,384
0
174,304
6,210
(3,457)
177,O57
37.15920h
8.037Byc
DD.SE
DD.SG
DD-SG
DD-SO
DD-OTHER
DD-OTHER
DD-OTHER
DD.OTHER
DD-OTHER
DD-S]TUS
DD.SITUS
'186M
186M
186M
186M
186M
186M
186M
Total SITUS
Total SG
Total-SO
OTHER
OTHER
OTHER
OTHER
OTHER
SITUS
SITUS
DMSC
LABOR
P
PTD
T
T
LABOR
186M
186M
186M
186M
SE
SG
SG
SO
976P
P
T
976q,292
8,280
78
90,292
w,292
DMSC 78
1,526
78
1,526
0
0
115
0
52 32
98,572
78
Total-DD
DDSS FACTOR
DEFSG FACTOR
DDSO6 FACTOR
Major Adjustment
1998 Early Retirement
19S) Early Retirement
Transition Planning
Environmental Clean-up
Y2K
Subtotal Major Adjustments
Total 186M SO
Total 182 &186
LABOR
LABOR
PTD
ESD
PTD
101,267
0.00%
100.00%
100.00%
78
1,089,400
91,321
0.0000%
t1.8003%
0.0000c6
8,311
0.000006
8.399706
0.0000%
32
0.0000%
0.0000o/o
0.0000%
0.00000/6
0.0000%
0.0000%
1,6(N
0.0000%
0.0000%
100.0000%
Total
78
557,990 50,692 177,088 293,2U 10,375
Production Transmission Poles & Wres Customors Miscellaneous
DMSC
DPW
CUST
ESD
GP
RETAIL
LABOR
P
PT
PTD
T
TAXDEPR
TD
100.0000%
100.0000%
100.0000%
'100.0000%
't00.0000%
100.0000%
100.00000i5't00.0000%
100.0000%
't00.0000%
100.0000%
100.00000/6
100.0000%
0.00000,6
0.0000%
0.000006
30.0000%
44.5814%
0.0000%
43.5484%
100.0000%
62.3888%
45.3U2%
0.0000%
57.9163%
0.0000%
0.0000%
0.0000%
0.0000%
10.0000%
27.3021o/o
0.0000%
8.6542%
0.00000/6
37.6112%
27.31170h
'100.0000oi6
19.7il2o/o
49.9337%
0.0000%
100.00000,6
0.00000,6
60.0000%
27.4072%
0.0000%
35.9489%
0.0000%
0.00000/6
27.3U2%
0.000070
21.4595o/n
50.0663%
0.0000%
0.000006
100.0000%
0.00000,6
0.7093%
100.0000%
1 1.8485%
0.0000%
0.00000/6
0.0000%
0.0000%
0.8601%
0.0000o/5
100.0000%
0.0000%
0.0000%
0.00000/6
0.0000%
0.0000%
0.0000%
0.0000%
0.0000%
0.000006
0.000006
0.0000%
0.0000%
DITBALRL
Pacific Division Total Production Transmission DPW CUST DMSC
Production P 10,083,490 10,083,490TransmissionT9,546,703-9,546,703Distribution DPW 2.823,945 2,823,945
PacifiCorp
12 Months Ended December 2020
Deferred lncome Tax - Balance
(e7,0e3)
s,2t9
General
Mining Plant
Total Pacific Division
Utah Division
Production
Transmission
Distribution
General
Mining Plant
Total Utah Division
PACIFICORP
Prod / Other Prod
Cholla Unit 4
Gadsby Unit 4, 5 & 6
Hydro-PPL
Hydro-UPL
Transmission
Distribution
General/ lntangibles
Mining
WCA - CAEE 2007+
WCA - CAGE 2007+
WCA - CAGW 2007+
WCA_CAGW 2007+ -Marengo
WCA CAGW 2007+ -Goodnoe
WCA - General 2007+
WCA - JBG 2007+
OREGON EXTRA BOOK DEPR
Total PC (Post Merger)
Total Deferred Taxes
ACCMOITRL FACTOR
Rocky Mountain Power
Exhibit No. 48 Page 50 of 171
Case No. PAC-E-21-07
Witness: Robert M. Meredith
(273,894)(8,s82)G
P
P
T
(131,499)
5,219
(233,1 17)
21,812,265 9,957,210 9,313,586 2,550,0s1 (8,582)o
DPW
21,122,979
20,702,562
18,586,104
(1,231 ,053)
(7 _467\
21,122,979
20,702,562
(44s,491)
'18,586,104
(s21,066)b
P
(2s0,169)(16,327)
(7 _487\
59,173,125 20,865,342 20,259,072 18,065,038 (16,327)0
367,793,639 367,793,639(1,888,916) (1,888,916)4,704,160 4,704,160
21,586,724 21,586,7246,683,970 6,683,97032373.262 - 32.473,262660,995,740 660,995,74017.153,13',t 3,485,784 6,179,470 7,260,380 227 ,4971,966 1,966(3,000) (3,000)
1,267,105,494 790,532,301 476,573,193
320,143,705 199,733,914 120,409,791
(61 ,149,71 1 ) (61,149,71 1)0-123,293,002 25,0s5,062 M,416,694 52,186,048 1,635,198
110.917,222 110,917,222
lR) 17R)qq\ tA),t7R )OA\ - - - _
2,787 ,632,088 1 ,385,274,815 680,052,410 720,442,168 1 ,862,695
P
P
P
P
?
T
DPW
G
P
P
PT
PT
P
P
G
P
P
ACCUMDIT
2,868,617,478 1 ,416,097,367 709,625,068 741 ,057 ,257 1 ,837,786
,t00.00%49.370/o 24.74V.25.830/o 0.06%
40.9166%9.9626o/o 30.9540o/o 0.0000%
0
0.00%
DMSC
DPW
DDS2
CUST
ESD
G
GP
LABOR
P
PT
PTD
T
TAXDEPR
TD
Total
100.00%
100.000/o
100.00%
100.00%
100.00o/o
100.00olo
100.00%
't 00.000/o
100.000/o
100.00%
100,000/o
100.00%
100.00%
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Exhibit No.48 Page 155 of 171
Case No. PAC-E-21-07
Vvitness: Robert M. Meredith
Func FactoaTabla
Rocky l{ounbin Pffi
Cost Of S.ryi6 By Ra. Sch6dub
Sbtc ot ld.ho
2020 Proto@l
Adiustod ,l 2 t orth3 End.d D.cfrb{ 2021}
B c E G H
FACTOR ilAME Di.riburi6n Rdril Xi.c TOT I DBcdDtion
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Case No. PAC-E-21-07
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