UNBUNDLE.PDF

1
IDAHO PUBLIC UTILITIES COMMISSIONELECTRIC COSTS REPORTTOTHE GOVERNORANDTHE IDAHO LEGISLATUREJANUARY 26, 1998
2
January 27, 1998
The Honorable Philip E. Batt The Honorable John Hansen
Governor Co-chair
Statehouse Electric Utility Restructuring Interim Study
Committee Boise, ID 83720-0001 Statehouse
Boise, ID 83720-0081
The Honorable Jerry T. Twiggs The Honorable Ron Crane
President Pro Tem Co-chair
Idaho Senate Electric Utility Restructuring Interim Study
Committee
Statehouse Statehouse
Boise, ID 83720-0081 Boise, ID 83720-0038
The Honorable Michael K. Simpson
Speaker of the House
House of Representatives
Statehouse
Boise, ID 83720-0038
Re: Report to the Legislature
Gentleman:
Idaho Code § 61-338, as enacted by 1997 House Bill No. 399, requires the Commission to issue
periodic reports concerning the unbundling of electric utility costs in Idaho. The Commission has
completed its initial inquiry and prepared the attached report.
Three new dockets have been opened to further investigate the unbundled costs reported by the
three major investor-owned utilities regulated by the Commission. We will report the results of
these investigations when they become available. No further proceedings are anticipated to
review the cost information provided by the 26 publicly-owned utilities not under our regulatory
jurisdiction.
I hope you will find the report useful. If you have any questions, please do not hesitate to contact
me at 208-334-3427.
Sincerely,
Dennis S. Hansen
President i:wpfiles/umisc/legis.ltr
3
Table of ContentsExecutive Summary Page 1
Background Page 3
Ground Rules for Cost Studies Page 4
Cost Categories Page 7
Maps, Chart Appendix I
Average Utility Costs Appendix II
Summary of Cost Data Appendix III
Detailed Charts for Each Provider Appendix IV
4
IDAHO PUBLIC UTILITIES COMMISSIONREPORT TO THE GOVERNOR AND THE IDAHOLEGISLATUREON THE COSTS OF ELECTRIC SERVICE IN IDAHOEXECUTIVE SUMMARYIdaho Code §§ 61-338 and 61-339, as enacted by 1997 House Bill No. 399, direct the
Public Utilities Commission to obtain information from utilities operating in Idaho
concerning the costs of supplying electric energy to their customers separated among
utility functions.
The information collected reflects existing utility cost structures in which rates are set to
recover actual costs and a reasonable rate of return on investment, and costs are fully
allocated among the various services provided. Calendar year 1996 or a comparable
fiscal year were used for the embedded cost data.
Because a number of existing classes of service such as “industrial” and “irrigation”
include customers with widely differing demands and usage, costs have been separated at
the voltage level rather than the customer-class level. All costs have been expressed in
terms of cents per kilowatt hour because that is the way electric consumers have
traditionally been billed for the bulk of their power costs.
In addition to the categories required to be used by House Bill No. 399 -- generation,
transmission, and distribution -- the Commission has required separation of demand and
energy costs associated with generation, as well as the contribution received from
secondary sales and miscellaneous revenue. Fish mitigation, demand-side management
and alternative energy costs that are also associated with generation have been identified.
In addition to transmission and distribution facilities costs, the Commission has chosen to
separate metering, meter reading, billing, uncollectible accounts expense, “other” costs,
and public purposes including universal service and low-income assistance.
Appendix III of the report details the average costs by category for all the reporting
electric providers. Costs are broken into the categories of generation, transmission,
distribution facilities, metering, meter reading, billing, uncollectible accounts expense
and other expenses. Detailed information for each provider supplied by voltage level can
be found in Appendix IV.
At the request of Intervenors FMC and Potlatch, the Commission has opened Case Nos.
IPC-E-98-2, UPL-E-98-1, and WWP-E-98-1 to further investigate the separated cost data
filed by Idaho Power Company, PacifiCorp d.b.a. Utah Power and Light Company, and
the Washington Water Power Company and formal audits have been scheduled. In these
5
proceedings the Commission will address a number of issues raised by these and other
parties that were too complex and contentious to be resolved before the 1998 legislative
session. No further proceedings have been scheduled to review the cost information
provided by publicly-owned utilities not under the jurisdiction of the Commission. The
Commission will report the results of the investor-owned utility investigations when the
results become available.
6
IDAHO PUBLIC UTILITIES COMMISSIONREPORT TO THE GOVERNOR AND THE IDAHOLEGISLATUREON THE COSTS OF ELECTRIC SERVICE IN IDAHOBACKGROUNDIdaho Code §§ 61-338 and 61-339, as enacted by 1997 House Bill No. 399, direct the
Public Utilities Commission to obtain information from utilities operating in Idaho
concerning the costs of supplying electric energy to their customers. The Commission
was required by July 1, 1997 to begin proceedings to acquire cost information separated
among utility functions, consisting at a minimum of generation, transmission, and
distribution, but including other categories the Commission might deem relevant. All
investor-owned, cooperative, and municipally-owned utilities operating in Idaho, with the
exception of any investor-owned utility serving less than 1000 customers and any
cooperative serving less than 1000 customers and also serving consumers in other states,
must report cost information in the form and manner requested by the Commission.
There are three major investor-owned utilities (IOUs) and 26 publicly-owned utilities that
are required to report cost information in accordance with House Bill No. 399. Two
utilities, Inland Power and Light and Atlanta Power Company, are exempted. Appendix I
contains maps showing the service areas and a chart of residential rates for all IOUs and
publicly-owned utilities in Idaho.
Following enactment of House Bill No. 399, Governor Philip Batt expressed his interest
in public purpose investments made by utilities and urged the Commission to include
public purposes as a separate component of electric costs, and furthermore, to separately
identify costs associated with universal service, fish mitigation, low-income assistance,
conservation and alternate energy sources.
On June 30, 1997, the Commission issued a Notice of Inquiry opening Case No. GNR-E-
97-1,In the Matter of the Commission’s Own Investigation into the Costs Incurred by Idaho’sElectric Utilities in Providing Electric Service, and announcing a workshop on August 6,
1997. The workshop was held for two reasons. First, it was to provide direction to
utilities on the appropriate cost categories to be separated and analytical methods to be
used. Second, the workshop was to educate the general public and interested
stakeholders without technical backgrounds on the key issues associated with cost
separation to permit them to be better informed participants in future restructuring
debates. The Commission hired a consultant to give a formal presentation and to
moderate several panel discussions on the subject of cost separation. The workshop was
well-attended by persons representing a wide variety of interests including, among others,
7
publicly-owned utilities, investor-owned utilities, customer groups and environmental
organizations.
Following the workshop, the Commission issued a Notice of Scheduling and Proposed
Order
No. 27134 generally endorsing a methodology presented by Idaho Power as a model for
Idaho’s other electric providers to use in providing separated information; establishing
cost categories and ground rules for studies; finding that strandable costs are beyond the
scope of the proceeding; and asking for comment. The order also scheduled a technical
workshop for the Commission Staff and representatives of electric providers to resolve
technical issues.
Participants in the workshop included Idaho Power Company, PacifiCorp, the
Washington Water Power Company, and the Idaho Consumer-Owned Utility Association
(ICUA) representing 21 of the 26 publicly-owned utilities required to provide cost
information.
On November 18, 1997, the Commission issued Order No. 27211 adopting the
conclusions and recommendations from the technical workshop and addressing
comments in opposition to the Commission’s proposed order. The Commission found
some of the issues raised by Intervenors FMC and Potlatch to be on point but too
complex and contentious to be resolved before the 1998 legislative session. The
Commission stated its intention to open, upon receipt of cost information from investor-
owned utilities, three new dockets to address the issues raised by FMC and Potlatch and
examine in detail the cost data provided. It indicated, however, that no further
proceedings would be held to review the cost information provided by publicly-owned
utilities who are not under the jurisdiction of the Commission. Electric providers were
given until December 18, 1997 to file their cost information. Four small non-profit
providers were given an extension until January 18, 1998 to file their information and
permitted to make abbreviated filings that satisfy the minimum requirements of House
Bill No. 399.
8
GROUND RULES FOR COST STUDIESThe directions given to the electric providers were based on the underlying assumption
that the information provided should reflect the existing cost structure inherent in
regulated utility rates today. In today’s regulated environment, utilities are allowed to
charge rates to recover their prudently incurred actual costs and a reasonable rate of
return on investment, and costs are fully allocated among the various services provided.
The separated costs may or may not reflect prices that would be charged in an
unregulated market.BASIC DATAAll studies use calendar year 1996 or comparable fiscal-year embedded-cost data. No
reconciliation of costs and rates or revenues has been required. In the case of investor-
owned utilities, the cost data has been normalized for weather and stream flows.
Normalization adjustments reflect the mix between hydropower and other generation as
well as what loads would be under normal weather conditions. Because publicly-owned
utilities purchase most of their power rather than generating it themselves, their per-
kilowatt-hour costs are not as sensitive to weather and stream flows as those of
generating utilities. Therefore, they were not required to file normalized data.
Utilities have used their authorized or other reasonable cost of capital in determining
return on investment. Neither PacifiCorp nor Washington Water Power has had a recent
case before the Commission in which its cost of capital was determined; therefore
authorized rates of return may not reflect current costs of capital. In its study, PacifiCorp
used a hypothetical weighted cost of capital of 9%, while Washington Water Power filed
using its authorized rate of 11.02% as well as its more appropriate current actual
regulated return of 9.58%. The Washington Water Power numbers in this report are from
the 9.58% filing. Idaho Power used the 9.306% agreed to in Case No. IPC-E-95-11.
ICUA members used their actual margins or 11%.USE OF THE IDAHO POWER FORMATIn July 1997, Idaho Power filed its report Unbundled Cost Information with the
Commission. The basic methodology, described as a modified revenue requirement
approach, used by Idaho Power in preparing this report was adopted by the Commission
as a model for other utilities to use in preparing their own information. The study was
based on historical accounting information allocated using methods accepted by its
regulatory agencies. Idaho Power presented its approach at the August workshop. In
Order No. 27134, issued following the workshop, the Commission indicated agreement
with the Idaho Power approach and urged other electric providers to use it as a guide for
their own studies. In general, utilities have followed the Idaho Power approach.ALLOCATION OF COSTS AMONG CUSTOMER GROUPS
9
Because it is more expensive to serve some customers than others, costs have
traditionally been allocated among customer groups with similar characteristics.
Customers whose demand for power is highest at the time of the system peak (for
example, space heating and cooling customers) are more expensive to serve than
customers who use a constant amount of power each day of the year. Customers who
take power at transmission-level voltages are cheaper to serve than customers for whom
power must be “stepped down” to lower household-level voltages. Billing and other
customer-related costs must be spread over a smaller number of kilowatt hours for
residential customers than for industrial customers. Costs, therefore, must be separated
not only among cost categories, but also among customer groups.
Customers have traditionally been grouped by classes such as residential, industrial, etc.
However, a number of existing customer classes include customers with fairly large as
well as small usage (for example, the irrigation class includes everything from small
family farms to large corporate operations). Therefore, for this report customers have
been grouped according to the voltage levels at which they take service, and costs have
been separated at the voltage rather than the class level to provide more accurate and
useful information. Also, because voltage level is more consistent among utilities, it is
hoped that this grouping may foster comparability of information from utility to utility.
To make the information more useful to customers, the reports were required to include
adequate descriptions to allow customers to understand how the voltage-level information
relates to them.
All costs have been expressed in terms of cents per kilowatt hour because that is the way
electric consumers have traditionally been billed for the bulk of their power costs. In a
restructured industry, this tradition might not survive and customers might find a larger
portion of their bill does not vary with their usage. For example, in its unbundling report
Idaho Power points out that it is possible that customers using the distribution facilities of
a utility may pay a fixed monthly fee for that usage because many distribution costs are
not usage sensitive.
Currently, customer rates are based on the average costs of serving all the customers in a
class such as “residential” even though the cost of serving individual customers can be
quite different. This practice is referred to as “postage stamp” pricing. Idaho Power also
points out that its study maintains the postage stamp concept and does not consider line
distances or population densities as a factor. If these factors were taken into
consideration, the cost of serving customers with similar load characteristics in the same
class of service but living in different areas might be shown to be different.FUNCTIONALIZATION AND CLASSIFICATION OF COSTSUtility costs have traditionally been functionalized between production (or generation),
transmission, and distribution. Much of the functionalization of costs occurs directly as
costs are incurred and recorded on the financial books of the utility in accordance with
10
the Uniform System of Accounts (USOA) required by the Idaho PUC for investor-owned
utilities under its jurisdiction. Although municipal and cooperative utilities have not
traditionally accounted for costs using the USOA, members of the Idaho Consumer-
Owned Utility Association volunteered to present their cost information in conformance
with the USOA, making their data comparable to data filed by investor-owned utilities.
Expenditures that relate to more than one function generally fall into the category of
general and administrative costs. These costs must be allocated among generation,
transmission, and distribution. In the past, utilities developed their preferred allocation
methods for assigning administrative costs, and unless they were found to be
unreasonable, these methods were accepted by the Commission. Because there is no one
correct method of allocating costs, allocation methods may differ between utilities.
To allocate functionalized costs among customer groups, they must first be classified as
demand, energy, or customer-related. Demand costs are those that are related to capacity,
or readiness to serve. Energy costs vary according to consumption, and customer costs
vary with the number of customers, regardless of power consumption. The classification
of costs as demand, energy or customer-related also differs among utilities. The
methodology appropriate for each utility will depend to some degree on the operating
characteristics of that utility. Utilities were instructed for purposes of this report to use
the method approved by the Commission for them. ICUA members have individually
chosen a method they believe is appropriate to reflect the operating characteristics of
their utilities.
11
COST CATEGORIESHouse Bill No. 399 requires cost information to be separated among utility functions,
consisting at a minimum of generation, transmission, and distribution services, but
including other categories the Commission may find relevant. Governor Batt requested
that the Commission also separately identify a number of cost categories related to
“public purpose” expenditures. As a result of the Governor’s request, comments received
in writing and at the two workshops, the Commission has identified a number of cost
categories that should provide information that will be useful in understanding Idaho’s
current electric costs.GENERATIONGeneration includes the cost of power supply whether obtained through a utility’s own
generation facilities or through power purchased from an entity such as the Bonneville
Power Administration (BPA). In Idaho, investor-owned utilities generate most of their
own power, while publicly-owned utilities purchase the bulk of their power. The cost
data filed by Idaho utilities show that, on average, generation costs are the single major
cost of providing power, accounting for between 50% and 60% of total utility costs.
These costs range from
2.31 cents per kilowatt hour for Idaho Power to 3.28 cents per kilowatt hour for
PacifiCorp.
Care should be taken in comparing these numbers with prevailing market index prices.
These generation costs represent long-term power supplies complete with all ancillary
services, whereas market index prices usually do not.
Because large-volume utility customers pay both demand and energy charges, electric
providers were required to break generation charges into demand and energy categories.
Demand-related costs are incurred to ensure that power will be available when needed
during peak-usage periods. They consist primarily of return on investment in generating
facilities as well as related depreciation expense for generating utilities and demand
charges for purchasing utilities. Energy-related costs are those that vary with the output
of electricity and include variable costs such as fuel, purchased power, and operating and
maintenance expenses. Purchasing utilities pay an energy or commodity rate per kilowatt
hour of wholesale power purchased. In practice, some fixed costs have been allocated to
energy and some operation and maintenance expenses have been considered fixed and
therefore allocated to demand. The classification of these expenses will likely be one of
the issues addressed in the cases opened to consider investor-owned utilities’ separated
costs.
During non-peak periods and periods of excess capacity, a utility is frequently able to
generate and sell excess power from facilities included in its rate base. Because the
facilities are supported by retail customers, these surplus sales and other miscellaneous
utility revenue have traditionally been used to offset generation costs in setting retail
12
rates. The Commission has, therefore, required that this contribution be separately
identified under the generation category.
Several commenters took exception to categorizing alternative energy sources, demand-
side management (DSM), and fish mitigation as public purposes when in fact they are
generation or power supply costs. They argue that removing these costs from generation
would be misleading and would understate generation costs.
While they may be imposed by public bodies, fish mitigation costs are incurred as a
direct consequence of constructing hydroelectric projects. There is no difference between
these costs and other environmental mitigation costs such as scrubbers on fossil fuel
generating stations. Finally, practically speaking, it is almost impossible to capture all
fish mitigation costs embedded in a utility’s rate base and operating costs. Utilities have
agreed to break out those embedded costs that are most easily identifiable and to track
these costs in the future.
Alternative energy sources may be the category that most clearly belongs under
generation. While the costs associated with these plants may be slightly higher than more
traditional generation, these resources generate power and produce revenue in precisely
the same way other generating resources do. Examples are Washington Water Power’s
Kettle Falls Plant powered by wood waste and Idaho Power’s solar installations. They
exist not because they were required by a public agency, but because the utilities believed
they were reasonable investments.
Since the early 1980s, the Commission has encouraged utilities to develop programs to
reduce demand on their systems and thereby avoid building expensive new generating
facilities. Amounts that were considered reasonable payments for DSM resources were
based on the costs a utility could avoid if it did not have to acquire new generation.
Because DSM costs were incurred in lieu of adding generation and were based on
avoided generating costs, they were traditionally considered to be “generating costs.”
Whether future DSM costs will be considered generation costs will depend on whether
the electric industry is restructured. If generation is deregulated as proposed, it is highly
unlikely that future DSM expenditures will be considered generation costs. For purposes
of this report, they are shown as they have traditionally been considered, as generation
costs.
Washington Water Power notes in its unbundling report that its DSM Tariff Rider,
Schedule 91 is a revenue surcharge and is intended to be a non-bypassable distribution
charge even though the Rider is applied to what may be considered generation costs.
Idaho Power has a filing before the Commission in which it proposes to allocate DSM
costs incurred prior to 1994 as they have traditionally been allocated but to allocate costs
13
incurred since 1994 based upon the ability of the customer class to participate in DSM
programs.NON-GENERATIONTransmission facilities transport energy at high voltage levels from generation sites to
load centers and, in some cases, to large end-use customers. Generally speaking,
distribution facilities connect all but the very largest consumers to the electric system,
with customers taking service at different voltage levels. Although the use of the
transmission system for wholesale sales and wheeling is regulated by the Federal Energy
Regulatory Commission (FERC), the cost of transmission and distribution services to
provide retail sales to IOU customers in Idaho is regulated by the Idaho Public Utilities
Commission. Purchasing utilities pay their wholesale
providers to have power delivered to their service areas. Although many of the publicly-
owned utilities included this cost under purchased power, it has been categorized as
“transmission” in this report.
Because of environmental and economic considerations, it is assumed that the actual
transmission of energy over electric transmission and distribution wires will continue to
be a monopoly service and therefore regulated. Some ancillary services such as
scheduling, load following, load shaping, voltage support, and system reserves, as well as
distribution and customer services such as metering, meter reading, billing, and other
customer services may not be considered monopoly services.
While they are needed to facilitate transmission, most ancillary services are actually
generation-related. Although these services related to wholesale transmission have
theoretically already been unbundled, costs for them are still being developed at the
federal level. Utilities have not, therefore, been required to separate retail costs for these
services. The average cost of transmission is .49 cents per kilowatt hour.
The Commission believes that it is appropriate to separately identify the costs of
potentially competitive distribution and customer services. For purposes of this report,
metering, meter reading, and billing services have been identified as potentially
competitive and listed separately from distribution facilities and other customer-related
costs. These categories average .27 cents per kilowatt hour. Distribution facilities costs
include return on distribution plant including poles, wires and transformers, as well as
expenses such as depreciation, tree trimming, etc. Distribution facilities costs average
1.73 cents per kilowatt hour. Uncollectibles, or bad debt expense, has been separately
identified because it relates to all other services for which bills have been rendered. It
averages .02 cents per kilowatt hour. An appropriate method of allocation has not been
developed, but will be necessary in the future if restructuring occurs.PUBLIC PURPOSESAfter moving demand-side management, fish mitigation and alternative energy sources to
generation, there remain two categories of public purposes. These are universal service
14
and low-income assistance. At the technical workshop the utilities indicated they spend
very little on low-income assistance at this time. (Project Share, a low-income assistance
program, is financed through voluntary contributions from utility customers. LIHEAP, or
Low Income Home Energy Assistance Program, is a federal program that also provides
heating assistance to low-income individuals. Neither program is financed through utility
rates.) There also does not appear to be any universal service costs that can be identified.
Nevertheless, because there may be future costs incurred by utilities in these categories, it
seems reasonable to retain the categories for future use.STUDY RESULTSFor a number of reasons, the separated costs for a customer group will not equal that
group’s current rate. One reason is that costs may have changed since rates were last set,
and even if, overall, rates still produce reasonable levels of revenue, individual rates are
no longer cost-based. Another reason is that not all rates were strictly cost-based to begin
with. For investor-owned utilities, the Commission has traditionally considered cost
important, but recognized that cost-of-service studies are not precise and that cost is only
one among a number of factors to be considered in setting rates. Other factors include
the ability of a customer group to pay and how large an increase would be required to
move a class to its cost-of-service. The Commission has for a number of years been
moving rates that were clearly not cost-based toward cost-of-service, but has tried to
minimize the resulting economic hardships on classes that had previously been
subsidized.
The separated costs reported by electric service providers in Idaho have been summarized
and presented as follows:
Appendix I contains maps showing the service areas and a chart of residential
rates for all IOUs and publicly-owned utilities in Idaho.
Appendix II contains charts showing national average utility costs as well as the
average costs of generation, transmission, distribution, and other for the three
Idaho investor-owned and the publicly-owned utilities.
Appendix III contains a summary of the cost data by category for each reporting
provider.
Appendix IV contains a detailed chart for each provider showing separated costs
per kilowatt hour by voltage level.FURTHER PROCEEDINGSThe Commission has opened Case Nos. IPC-E-98-2, UPL-E-98-1, and WWP-E-98-1 to
investigate the cost data filed by Idaho Power Company, PacifiCorp d.b.a. Utah Power
15
and Light Company, and the Washington Water Power Company. The Commission has
scheduled audits of the underlying data of each of these investor-owned utilities.
Intervenors in these cases may conduct formal discovery. In addition to verifying the
data presented, it is expected that the issue of whether and how traditional cost allocation
methods may have to change in a competitive environment will be addressed.
16
APPENDIX IMAPS OF SERVICE AREASANDCHART OF RESIDENTIAL RATESAPPENDIX IICHARTS OF AVERAGE UTILITY COSTSAPPENDIX IIISUMMARY OF COST DATAAPPENDIX IVDETAILED CHARTS FOR EACH PROVIDERIdaho Power
PacifiCorp
Washington Water Power
Albion
City of Bonners Ferry
City of Burley
Clearwater Power Company
City of Declo
Fall River Rural Electric
City of Heyburn
Idaho County Light and Power
City of Idaho Falls
Kootenai Electric Cooperative, Inc.
Lost River Electric Co-op
Lower Valley Power and Light
Northern Lights, Inc.
City of Plummer
Raft River Rural Electric Co-op
City of Rupert
Rural Electric Company
17
Salmon River Electric Company
City of Soda Springs
South Side Electric Lines
Unity Light and Power Company
City of Weiser
East End Mutual Electric Company, LTD.
Farmer’s Electric Company
City of Minidoka
Riverside Electric Company
PayettePayettePayettePayettePayettePayettePayettePayettePayette
BoiseBoiseBoiseBoiseBoiseBoiseBoiseBoiseBoise
LewistonLewistonLewistonLewistonLewistonLewistonLewistonLewistonLewiston
Coeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'AleneCoeur d'Alene
SandpointSandpointSandpointSandpointSandpointSandpointSandpointSandpointSandpoint
McCallMcCallMcCallMcCallMcCallMcCallMcCallMcCallMcCall
AtlantaAtlantaAtlantaAtlantaAtlantaAtlantaAtlantaAtlantaAtlantaPowerPowerPowerPowerPowerPowerPowerPowerPower
Twin FallsTwin FallsTwin FallsTwin FallsTwin FallsTwin FallsTwin FallsTwin FallsTwin Falls
SalmonSalmonSalmonSalmonSalmonSalmonSalmonSalmonSalmon
Sun ValleySun ValleySun ValleySun ValleySun ValleySun ValleySun ValleySun ValleySun Valley
Utah Power
Idaho Service Areas of
Investor Owned Utilities
PocatelloPocatelloPocatelloPocatelloPocatelloPocatelloPocatelloPocatelloPocatello
RexburgRexburgRexburgRexburgRexburgRexburgRexburgRexburgRexburg
Idaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho Falls
Idaho Power
Idaho Power & Utah Power
Overlap Area
Washington Water Power
Note: If this map does not display correctly and you would like to receive a printed copy, contact
the Idaho Public Utilities Commission.
Northern Lights, Inc.
Electric Co-ops, Mutual and
Municipalities within Idaho
Legend
Kootenai Electric Co-op, Inc.
Inland Power & Light
Clearwater Power Company
Salmon River Electric Co-op
Lost River Electric Co-op, Inc.
Fall River Electric Co-op
Bonners Ferry, Idaho Falls, Soda
Mini-Cassia Mutuals & Co-ops
Mini-Cassia Municipalities
Other Municipalities
Power & Light, Rural Electric
Albion, Burley, Declo, Heyburn
Minidoka, Rupert
Springs, Plummer, Weiser
Electric, South Side Electric, Unity
East End, Farmers Electric, Riverside
Idaho County Light & Power Co-op
Lower Valley Power & Light Co.
Raft River Rural Electric Co-op, Inc.
Bonners FerryBonners FerryBonners FerryBonners FerryBonners FerryBonners FerryBonners FerryBonners FerryBonners Ferry
PlummerPlummerPlummerPlummerPlummerPlummerPlummerPlummerPlummer
WeiserWeiserWeiserWeiserWeiserWeiserWeiserWeiserWeiser
Idaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho FallsIdaho Falls
Soda SpringsSoda SpringsSoda SpringsSoda SpringsSoda SpringsSoda SpringsSoda SpringsSoda SpringsSoda Springs
Note: If this map does not display correctly and you would like to receive a printed copy, contact
the Idaho Public Utilities Commission.
Residential Prices for Electricity(October, 1997) Residential Rate Design Total Bill & Avg. $/kwh
(elecratw.exl) Average cents/kwh Monthly $/kwh Minimum
(1000 kwh)(3000 kwh) City County Area @ 1000 kwh @ 3000 kwh
1 Idaho Falls Electric Idaho Falls Bonneville E 5.25 0.03900 5.25 44.25 122.25
avg/kwh 4.4 4.1 0.0443 0.0408
2 Soda Springs Muni.Soda Springs Caribou E 5.50 0.04155 5.50 47.05 130.15
avg/kwh 4.7 4.3 0.0471 0.0434
3 Lower Valley P. & L.Afton, WY Bonneville E 10.00 0.05072 10.0 60.72 159.56
avg/kwh 6.1 5.3 add'l over 1,000 kwh 0.04942 0.0607 0.0532
4 Fall River Rural Ashton Fremont E 26.22 incl. 200 kWh 26.22 71.10 166.50
0.0561 next 1200 kWh
0.0456 over 1400 kWh
avg/kwh 7.1 5.6 0.0711 0.0555
5 Salmon River Electric Challis Custer C 19.65 0.04000 19.65 59.65 139.65
avg/kwh 6.0 4.7 (excludes seasonal)0.0597 0.0466
6 Lost River Electric Mackay Custer C 9.45 0.03750 9.45 46.95 121.95
avg/kwh 4.7 4.1 0.047 0.0407
7 Raft River Electric Malta Cassia SC 4.00 0.02800 15.00 52.00 @ 6 KW 124.00
avg/kwh 5.2 4.1 (Note: averages based on est. KW demand) per KW demand 0.052 0.0413
8 South Side Electric Declo Cassia SC 17.00 0.03600 9.50 47.70 125.00
avg/kwh 4.8 4.2 (with 10% discount)0.0477 0.0417
9 Unity Light Burley Cassia SC 9.00 0.03870 9.00 47.70 125.10
avg/kwh 4.8 4.2 0.0477 0.0417
10 Albion Light Albion Cassia SC 9/26/96 9.00 0.06100 9.00 70 192
avg/kwh 7.0 6.4 0.07 0.064
11 Burley Munic.Burley Cassia SC 8.00 0.04434 8.00 52.34 141.02
avg/kwh 5.2 4.7 0.0523 0.047
12 Declo Munic.Declo Cassia SC 9/26/96 19.00 incl.300kwh 19.00 44.44 122.56
0.04340 add'l.kwh
avg/kwh 4.4 4.1 (with 10% discount)0.0444 0.0409
13 Minidoka Elec. Dept.Minidoka Minidoka SC 6.50 0.05500 6.50 61.50 171.50
avg/kwh 6.2 5.7 0.0615 0.0572
14 East End Mutual Rupert Minidoka SC 6.67 0.04900 6.67 45.867 124.27
avg/kwh 4.6 4.1 (with 20% discount)0.0459 0.0414
15 Rural Electric Rupert Minidoka SC 11.00 0.04070 11.00 51.70 133.10
avg/kwh 5.2 4.4 (2% for level pay not incl.)0.0517 0.0444
16 Farmers Electric Rupert Minidoka SC
avg/kwh n.a. n.a.
17 Heyburn Electric Heyburn Minidoka SC 6.00 0.03376 6.00 37.77 101.92
avg/kwh 3.8 3.4 (with 5% discount)0.0378 0.034
18 Rupert Electric Rupert Minidoka SC 10.00 0.04144 10.00 51.44 134.32
avg/kwh 5.1 4.5 0.0514 0.0448
19 Riverside Electric Rupert Minidoka SC 6.00 0.04824 6.00 43.39 120.58
avg/kwh 4.3 4.0 (with 20% discount)0.0434 0.0402
20 Weiser Light Weiser SW 2.50 0.04710 2.50 49.60 143.80
avg/kwh 5.0 4.8 (mirrors Idaho Power res. rates)0.0496 0.0479
21 Inland Power Spokane, WA Bonner N 14.00 0.04300 14.00 57.00 143.00
avg/kwh 5.7 4.8 0.057 0.0477
22 Plummer Electric Plummer Benewah N 8.65 incl.50 kwh 8.65 59.095 139.2
0.05310 next 950 kwh
0.04070 next 1000 kwh
0.03940 over 2000 kwh
avg/kwh 5.9 4.6 0.0591 0.0464
23 Northern Lights Sandpoint Bonner N 21.00 21.00 66.90 183.13
0.04900 first 500 kwh
0.04280 next 750kwh
0.06030 next 6000kwh
0.05100 all add'l. kwh
avg/kwh 6.7 6.1 0.0669 0.061
24 Bonners Ferry Bonners F.Boundary N 3.50 0.03900 3.50 42.50 120.50
avg/kwh 4.3 4.0 (inside city)0.0425 0.0402
25 Idaho County Light Grangeville Idaho N 12.50 0.07100 first 1500 kwh 83.50 179.00
0.04000 add'l kwh
avg/kwh 8.4 6.0 0.0835 0.0597
26 Kootenai Electric Hayden Lake Kootenai N 25.00 incl. 416 kWh 25.00 55.04 155.04
0.06000 417 to 500 kWh
0.05000 add'l.kWh
avg/kwh 5.5 5.2 0.055 0.0517
27 Clearwater Power Lewiston Nez Perce N 11.00 0.06180 to 1600 kwh 72.80 173.02
,0.04510 add'l kwh
avg/kwh 7.3 5.8 0.0728 0.0577
28 Idaho Power 2.50 0.04710 2.50 49.60 143.80
avg/kwh 5.0 4.8 (incl. -.001552 PCA -.000384 Rev. Shar.)0.0496 0.0479
29 Washington Water Power 0.00 8.50 43.32 150.10
0.04026 first 600 kwh
0.04790 next 700 kwh
0.05436 add'l kwh
avg/kwh 4.3 5.0 (incl. +.00068 DSM rider - .00223 PCA)0.0433 0.05
30 Utah Power & Light Sum-0.00 0.08693 9.57 86.93 260.80
summer avg/kwh 8.7 8.7 Sch. 1, Residential mer May-Oct.(w. avg. .011339 BPA credit)0.0869 0.0869
winter avg/kwh 6.6 6.6 (excluding time-of-day)Win-0.00 0.06587 9.57 65.867 197.6
nonTOD 1996 avg.7.316,523 cust.ter Nov.-Apr.(w. avg. .009037 BPA credit)0.0659 0.0659
Sum-Peak Hours 12.56 0.09361 12.56 n.a.n.a.
summer avg/kwh n.a.n.a.mer Off-Peak 0.02483 n.a.n.a.
winter avg/kwh n.a.n.a.Win-Peak Hours 12.56 0.08063 12.56 n.a.n.a.TOD 1996 avg.5.415,110 cust.ter Off-Peak 0.02395 n.a.n.a.
31 Atlanta Power Elmore 0.00 incl. 500 kwh 81.00 81.00 81.00
0.05000 add'l. kwh
avg/kwh 8.1 2.7 0.081 0.027
UNBUNDLING REPORT JAN. 26, 1998APPENDIX I PAGE 3 OF 3
NATIONAL AVERAGE OF UTILITY COSTSGeneration
5.3 ¢/kWh
74%
0.5 ¢/kWh
7%
1.3 ¢/kWh
19%
IDAHO CONSUMER OWNED UTILITIES AVERAGE COSTSTransmission
0.39 ¢/kWh
7%
0.31 ¢/kWh
6%
1.88 ¢/kWh
35%
2.72 ¢/kWh
52%
Total Cost = 5.30 ¢/kWh
IDAHO POWER COMPANY AVERAGE COSTSOther
0.49 ¢/kWh
12%
2.31 ¢/kWh
54%
1.19 ¢/kWh
28%
0.23 ¢/kWh
6%
PACIFICORP AVERAGE COSTSGeneration
3.28 ¢/kWh
52%
0.73 ¢/kWh
11%
1.97 ¢/kWh
31%
0.41 ¢/kWh
6%
Total Cost = 6.39 ¢/k/Wh
WASHINGTON WATER POWER AVERAGE COSTSDistribution
1.33 ¢/kWh
26%
0.26 ¢/kWh
5%
3.00 ¢/kWh
60%
0.45 ¢/kWh
9%
UtilityGenerationTransmissionDistributionMeteringMeterBillingUncollectibleOtherTotalReadingAccounts (1)¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh
Investor Owned Utilities Idaho Power Company 2.31 0.23 1.19 0.15 0.07 0.24 0.01 0.01 4.22
PacifiCorp 3.28 0.73 1.97 0.23 0.06 0.08 0.02 0.02 6.39
Washington Water Power 3.00 0.45 1.33 0.04 0.04 0.13 0.02 0.03 5.04
Atlanta Power Company (5)Consumer Owned Utilities City of Albion (2)2.90 0.64 1.94 0.03 0.01 0.14 0.02 0.00 5.69
City of Bonners Ferry (2)2.19 0.33 1.68 0.04 0.02 0.16 0.02 4.44
City of Burley (2)2.71 0.47 1.29 0.07 0.04 0.02 0.04 4.64
Clearwater Power Co. (2) (4)2.56 0.62 5.10 0.04 0.04 0.17 0.00 8.60
City of Declo (2)2.94 0.60 1.12 0.03 0.01 0.08 0.01 4.79
Fall River Rural Electric (2)2.65 0.39 2.70 0.06 0.06 0.12 0.00 5.98
City of Heyburn (2)2.27 0.39 0.44 0.01 0.03 0.04 0.00 3.18
Idaho County Light and Power (2)2.66 0.52 3.80 0.07 0.10 0.29 0.07 7.51
City of Idaho Falls (2)2.60 0.42 1.49 0.03 0.05 0.08 0.04 4.72
Inland Power and Light Co. (5)
Kootenai Electric Cooperative 2.99 0.01 1.59 0.36 0.08 0.05 0.04 0.31 5.43
Lost River Electric Co-op (2)1.96 0.44 2.04 0.07 0.07 0.11 0.01 4.70
Lower Valley Power and Light (3) (4)0.22 0.44 1.79 0.00 0.10 0.17 0.00 2.72
Northern Lights, Inc. (2)2.56 0.49 3.21 0.04 0.08 0.31 0.09 6.78
City of Plummer (2)2.57 0.57 0.96 0.08 0.05 0.11 0.00 4.34
Raft River Rural Electric Co-op (2)2.33 0.59 1.15 0.06 0.04 0.04 0.05 4.26
City of Rupert (2)2.76 0.56 1.65 0.09 0.05 0.11 0.00 5.22
Rural Electric Company (2)2.29 0.47 1.39 0.06 0.04 0.14 0.00 4.38
Salmon River Electric Co-op (2) (4)2.52 0.45 1.96 0.06 0.05 0.19 0.10 5.33
City of Soda Springs (2)3.22 0.48 2.05 0.05 0.04 0.21 0.00 6.05
South Side Electric Lines (2)4.59 0.80 2.26 0.14 0.11 0.03 0.65 8.57
Unity Light and Power Company (2)2.83 0.52 0.84 0.11 0.01 0.05 0.02 4.38
City of Weiser 2.78 0.00 1.04 0.05 0.05 0.06 0.08 4.07
East End Mutual Electric Co-op (2)2.49 0.56 0.62 0.01 0.01 0.02 0.00 3.71
Farmers Cooperative (2)2.54 0.68 0.59 0.01 0.05 0.10 0.00 3.97
City of Minidoka (2)3.28 1.49 0.44 0.04 0.12 0.65 0.00 6.02
Riverside Electric Cooperative (2)2.48 0.68 1.04 0.01 0.03 0.08 0.00 4.32
Average2.64 0.52 1.68 0.07 0.05 0.14 0.02 0.05 5.15
UNBUNDLED ANNUAL AVERAGE COSTSELECTRIC UTILITIESIDAHOSummary1 2/27/98
NOTES: (1) Uncollectible Accounts costs are included with Billing costs if an amount is not shown in this column.
(2) Transmission Demand costs included under Purchased Power in this utilities unbundling report have been removed from Generation costs
and included in the Transmission costs category in this Appendix.
(3) Power supply costs have been filed confidential and, therefore, are not included in this Appendix.
(4) Some customer cost and usage information has been filed confidential and, therefore, is not included in this Appendix.
(5) This utility was exempt from filing unbundled cost information by statute.
Summary1 2/27/98
UtilityTotalDemandFishAlternativeLowUniversalSideMitigationEnergyIncomeServiceManagementServicesAssistance$$$$$$Investor Owned Utilities Idaho Power Company 4,548,875 4,548,875
PacifiCorp 943,281 295,923 582,209 1,821,413
Washington Water Power 7,254,814 4,269 5,089,549 12,348,632
Atlanta Power Company (2)Consumer Owned Utilities City of Albion 0
City of Bonners Ferry 0
City of Burley 0
Clearwater Power Co.18,963 18,963
City of Declo 0
Fall River Rural Electric 11,005 11,005
City of Heyburn 0
Idaho County Light and Power 51,000 51,000
City of Idaho Falls 172,723 172,723
Inland Power and Light Co. (2)
Kootenai Electric Cooperative 309,587 757,052 1,066,639
Lost River Electric Co-op 9,171 9,171
Lower Valley Power and Light 887,641 887,641
Northern Lights, Inc.0
City of Plummer 0
Raft River Rural Electric Co-op 46,432 26,282 72,714
City of Rupert 0
Rural Electric Company 0
Salmon River Electric Cooperative 7,000 7,000
City of Soda Springs 0
South Side Electric Lines 0
Unity Light and Power Company 0
City of Weiser 0
East End Mutual Electric Co-op (1)
Farmers Cooperative (1)
City of Minidoka (1)
Riverside Electric Cooperative (1)Total14,221,3531,057,2445,737,1790021,015,776(1) Commission Order No. 27268 allows abbreviated filing requirements for these utilities. These utilities have not been
required to unbundle the cost categories listed on this page.
(2) These utilities are exempt from filing unbundled cost information by statute.OTHER UNBUNDLED ANNUAL COSTSELECTRIC UTILITIESIDAHOGenerationPublic PurposesSummary2 2/27/98
IDAHO POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Small Secondary Primary Transmission (1)
Total
Generation
Demand Related Costs $21,594,181 19,991,117 8,941,407 349,024 50,875,729
Energy Related Costs $79,933,281 73,999,358 29,830,355 1,791,174 185,554,168
Net Benefit of $(6,016,661)(5,570,008)(2,574,284)(146,453)(14,307,406)
Secondary Sales Revenues
Demand Side Management $1,979,110 1,832,189 699,826 37,750 4,548,875
(including Low Income DSM)
Fish Mitigation $0
Alternative Energy Services $0
Total Generation $97,489,911 90,252,656 36,897,304 2,031,495 226,671,366
Transmission $11,016,284 8,284,450 3,552,614 173,227 23,026,575
Distribution Facilities $54,840,532 53,888,628 7,931,471 0 116,660,631
Metering $8,771,013 5,108,829 391,507 19,647 14,290,996
Meter Reading $5,818,965 1,274,545 83,793 4,191 7,181,494
Billing $22,147,576 1,558,473 10,200 533 23,716,782
Uncollectible Accounts $1,302,844 140,275 0 0 1,443,119
Other Customer Services (2)$457,926 495,616 109,988 7,111 1,070,641
Total Non-Generation $104,355,140 70,750,816 12,079,573 204,709 187,390,238
Load at Customer Level MWh 4,101,935 3,797,424 1,805,567 105,138 9,810,064
Billing Demand kW 0 12,137,263 3,737,356 221,386 16,096,005
Average No. of Customers No.305,307 23,216 141 8 328,672
Currently Served by Schedules *No.1,7,15,40,41,42,9,19,24,LP,LW,9,19,9,19,24
24,A,B,I,LU,I
OL,OP,UM
Number of Bills
Actual Bills 3,634,937 242,914 1,696 99 3,879,646
Unseasonalized (3)Bills 3,645,653 281,401 1,696 108 3,928,858
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
(1) Does not include Special Contract customer data.
(2) Includes Customer Assistance expense, intervenor funding, and regulatory commission fees.
(3) Actual number of bills adjusted to remove the effect of seasonal usage by irrigation customers; unseasonalized number
of bills is used to determine the monthly per unit cost of transmission, distribution facilities and metering.
ipc 2/4/98
SCHEDULE NO.TITLE OF SCHEDULE1 Residential Service
7 Small General Service
9 Large General Service
15 Dusk to Dawn Customer Lighting
19 Large Power Service
24 Irrigation Service
40 Unmetered General Service
41 Municipal Street Lighting Service
42 Traffic Control Signal Lighting Service
A Domestic and Small General Service
B Commercial and Small Industrial Service
I Irrigation Pumping Service
LP Large Power Service
LU Limited Use Service
LW Large Power Winter Service
OL Outdoor Lighting Service
OP Offpeak Service
UM Unmetered General Service
IDAHO POWER COMPANY
IDAHO POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Small Secondary Primary Transmission (1)
Average
Generation
Demand Related Costs ¢/kWh 0.53 0.53 0.50 0.33 0.52
Energy Related Costs ¢/kWh 1.95 1.95 1.65 1.70 1.89
Net Benefit of ¢/kWh (0.15)(0.15)(0.14)(0.14)(0.15)
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.05 0.05 0.04 0.04 0.05
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00
Alternative Energy Services ¢/kWh 0.00
Total Generation ¢/kWh 2.38 2.38 2.04 1.93 2.31
Transmission ¢/kWh 0.27 0.22 0.20 0.16 0.23
Distribution Facilities ¢/kWh 1.34 1.42 0.44 0.00 1.19
Metering ¢/kWh 0.21 0.13 0.02 0.02 0.15
Meter Reading ¢/kWh 0.14 0.03 0.00 0.00 0.07
Billing ¢/kWh 0.54 0.04 0.00 0.00 0.24
Uncollectible Accounts ¢/kWh 0.03 0.00 0.00 0.00 0.01
Other Customer Services (2)¢/kWh 0.01 0.01 0.01 0.01 0.01
Total Non-Generation ¢/kWh 2.54 1.86 0.67 0.19 1.91
Total ¢/kWh 4.92 4.24 2.71 2.13 4.22
Load at Customer Level MWh 4,101,935 3,797,424 1,805,567 105,138 9,810,064
Billing Demand kW 0 12,137,263 3,737,356 221,386 16,096,005
Average No. of Customers No.305,307 23,216 141 8 328,672
Currently Served by Schedules *No.1,7,15,40,41,42,9,19,24,LP,LW,9,19,9,19,24
24,A,B,I,LU,I
OL,OP,UM
Number of Bills
Actual Bills 3,634,937 242,914 1,696 99 3,879,646
Unseasonalized (3)Bills 3,645,653 281,401 1,696 108 3,928,858
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
(1) Does not include Special Contract customer data.
(2) Includes Customer Assistance expense, intervenor funding, and regulatory commission fees.
(3) Actual number of bills adjusted to remove the effect of seasonal usage by irrigation customers; unseasonalized number
of bills is used to determine the monthly per unit cost of transmission, distribution facilities and metering.
ipc 2/4/98
PACIFICORPUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Secondary Primary Transmission
Residential Small Large
Total
Generation
Demand Related Costs $7,193,424 1,519,051 11,006,863 402,910 3,765,963 23,888,211
Energy Related Costs $10,656,359 1,805,619 14,480,321 554,007 5,784,176 33,280,482
Total Generation $17,849,783 3,324,670 25,487,184 956,917 9,550,139 57,168,693
Transmission $3,798,082 823,091 5,774,771 210,370 2,146,397 12,752,711
Distribution Facilities $12,976,384 2,520,205 17,834,641 214,774 809,623 34,355,627
Metering $1,944,838 556,963 1,356,575 45,650 158,028 4,062,054
Meter Reading $757,578 110,874 208,425 377 1,057 1,078,311
Billing $806,088 158,977 354,704 779 7,600 1,328,148
Uncollectible Accounts $127,184 25,780 125,235 4,422 0 282,621
Other Customer Services $304,866 41,074 49,674 416 676 396,706
Total Non-Generation 20,715,020 4,236,964 25,704,025 476,788 3,123,381 54,256,178
Net Benefit of Secondary $(10,875,842)(2,305,035)(15,832,197)(590,533)(5,740,088)(35,343,695)
Sales Revenues**
Demand Side Management***$293,286 59,226 419,002 15,746 156,021 943,281
(including Low Income DSM)
Fish Mitigation***$92,009 18,580 131,448 4,940 48,946 295,923
Alternative Energy Services***$177,892 38,928 262,280 9,734 93,375 582,209
Load at Customer Level MWh 555,548 94,359 745,422 29,635 319,190 1,744,154
Billing Demand kW 4,782,227 529,602 2,376,439 62,279 540,897 8,291,444
Average No. of Customers No.40,143 6,363 3,479 9 20 50,014
Currently Served by Schedules *No.01, 36 23, 19, 104, 07 06, 10, 35 06, 08 Contracts, 09
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
** The net benefit of Secondary Sales Revenues includes Secondary and Non-Firm sales. Theses amounts have been deducted from
the Generation and Transmission Revenue Requirement to arrive at the Net Cost of Service for retail customers.
*** These amounts are included in the Generation Demand and Energy Cost of Service for retail customers shown above.
PACIFICORPUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Secondary Primary Transmission
Residential Small Large
Total
Generation
Demand Related Costs $7,193,424 1,519,051 11,006,863 402,910 3,765,963 23,888,211
Energy Related Costs $10,656,359 1,805,619 14,480,321 554,007 5,784,176 33,280,482
Total Generation $17,849,783 3,324,670 25,487,184 956,917 9,550,139 57,168,693
Transmission $3,798,082 823,091 5,774,771 210,370 2,146,397 12,752,711
Distribution Facilities $12,976,384 2,520,205 17,834,641 214,774 809,623 34,355,627
Metering $1,944,838 556,963 1,356,575 45,650 158,028 4,062,054
Meter Reading $757,578 110,874 208,425 377 1,057 1,078,311
Billing $806,088 158,977 354,704 779 7,600 1,328,148
Uncollectible Accounts $127,184 25,780 125,235 4,422 0 282,621
Other Customer Services $304,866 41,074 49,674 416 676 396,706
Total Non-Generation 20,715,020 4,236,964 25,704,025 476,788 3,123,381 54,256,178
Net Benefit of Secondary $(10,875,842)(2,305,035)(15,832,197)(590,533)(5,740,088)(35,343,695)
Sales Revenues**
Demand Side Management***$293,286 59,226 419,002 15,746 156,021 943,281
(including Low Income DSM)
Fish Mitigation***$92,009 18,580 131,448 4,940 48,946 295,923
Alternative Energy Services***$177,892 38,928 262,280 9,734 93,375 582,209
Load at Customer Level MWh 555,548 94,359 745,422 29,635 319,190 1,744,154
Billing Demand kW 4,782,227 529,602 2,376,439 62,279 540,897 8,291,444
Average No. of Customers No.40,143 6,363 3,479 9 20 50,014
Currently Served by Schedules *No.01, 36 23, 19, 104, 07 06, 10, 35 06, 08 Contracts, 09
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
** The net benefit of Secondary Sales Revenues includes Secondary and Non-Firm sales. Theses amounts have been deducted from
the Generation and Transmission Revenue Requirement to arrive at the Net Cost of Service for retail customers.
*** These amounts are included in the Generation Demand and Energy Cost of Service for retail customers shown above.
PACIFICORPUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Secondary Primary Transmission
Residential Small Large
Average
Generation
Demand Related Costs ¢/kWh 1.29 1.61 1.48 1.36 1.18 1.37
Energy Related Costs ¢/kWh 1.92 1.91 1.94 1.87 1.81 1.91
Total Generation ¢/kWh 3.21 3.52 3.42 3.23 2.99 3.28
Transmission ¢/kWh 0.68 0.87 0.77 0.71 0.67 0.73
Distribution Facilities ¢/kWh 2.34 2.67 2.39 0.72 0.25 1.97
Metering ¢/kWh 0.35 0.59 0.18 0.15 0.05 0.23
Meter Reading ¢/kWh 0.14 0.12 0.03 0.00 0.00 0.06
Billing ¢/kWh 0.15 0.17 0.05 0.00 0.00 0.08
Uncollectible Accounts ¢/kWh 0.02 0.03 0.02 0.01 0.00 0.02
Other Customer Services ¢/kWh 0.05 0.04 0.01 0.00 0.00 0.02
Total Non-Generation ¢/kWh 3.73 4.49 3.45 1.61 0.98 3.11
Total ¢/kWh 6.94 8.01 6.87 4.84 3.97 6.39
Net Benefit of Secondary ¢/kWh (1.96)(2.44)(2.12)(1.99)(1.80)(2.03)
Sales Revenues**
Demand Side Management***¢/kWh 0.05 0.06 0.06 0.05 0.05 0.05
(including Low Income DSM)
Fish Mitigation***¢/kWh 0.02 0.02 0.02 0.02 0.02 0.02
Alternative Energy Services***¢/kWh 0.03 0.04 0.04 0.03 0.03 0.03
Load at Customer Level MWh 555,548 94,359 745,422 29,635 319,190 1,744,154
Billing Demand kW 4,782,227 529,602 2,376,439 62,279 540,897 8,291,444
Average No. of Customers No.40,143 6,363 3,479 9 20 50,014
Currently Served by Schedules *No.01, 36 23, 19, 104, 07 06, 10, 35 06, 08 Contracts, 09
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
** The net benefit of Secondary Sales Revenues includes Secondary and Non-Firm sales. Theses amounts have been deducted from
the Generation and Transmission Revenue Requirement to arrive at the Net Cost of Service for retail customers.
*** These amounts are included in the Generation Demand and Energy Cost of Service for retail customers shown above.
Rate Schedules
SCHEDULE NO.TITLE OF SCHEDULE1 Residential Service
6 General Service - Large Power
7 Security Area Lighting
8 General Service - Medium Voltage
9 General Service - High Voltage
10 Irrigation and Soil Drainage Pumping Power Service
12 Street Lighting, Traffic and Other Signal System Service
19 Commercial and Industrial Space Heating
23 General Service
35 Optional Time-of-Day - General Service - Distribution Voltage
36 Optional Time-of-Day - Residential Service
Monsanto Company (Schedule No. 400)
Nu-West Industries, Inc.PACIFICORPPage 3
WASHINGTON WATER POWERUNBUNDLING REPORTIDAHOGNR-E-97-1Voltage Categories
Description Unit Small Secondary Primary Transmission
Total
Generation
Demand Related Costs $16,899,830 8,008,460 7,301,475 0 32,209,765
Energy Related Costs $34,084,147 21,443,728 15,103,143 0 70,631,018
Net Benefit of $(22,039,677)(12,974,032)(9,725,342)0 (44,739,051)
Secondary Sales Revenues
Demand Side Management $3,593,555 2,091,670 1,569,589 0 7,254,814
(including Low Income DSM)
Fish Mitigation $2,096 1,247 926 0 4,269
Alternative Energy Services $2,427,133 1,539,362 1,123,054 0 5,089,549
Total Generation $34,967,084 20,110,435 15,372,845 0 70,450,364
Transmission $5,263,934 3,091,206 2,316,420 0 10,671,560
Distribution Facilities $16,921,404 10,167,339 4,091,854 0 31,180,597
Metering $444,279 417,430 5,253 0 866,962
Meter Reading $865,091 80,692 1,694 0 947,477
Billing $2,903,301 135,404 1,137 0 3,039,842
Uncollectible Accounts $265,428 145,606 94,341 0 505,375
Other Customer Services $492,170 125,100 72,246 0 689,516
Total Non-Generation $27,155,607 14,162,777 6,582,945 0 47,901,329
Load at Customer Level MWh 1,123,227 710,142 515,028 0 2,348,397
Billing Demand kW N/A 2,418,108 1,057,213 0 3,475,321
Average No. of Customers No.91,977 4,328 36 0 96,341
Currently Served by Schedules *No.See Note 1
* List the rate schedule numbers for all schedules currently providing service under each voltage category.
Some rate schedules may provide service at more than one voltage.
All utilities need to provide a separate list of rate schedules by number with a description of the type of service provided
under each schedule.
Note 1 The customer categories include the rate schedules as listed below.
Small: Residential Service, Street and Area Lights and Non-Demand Metered General Service
Entire Schedules 001,006, 007, 041 through 046, 047 through 049, 070, 071 and 079
Non-demand metered subset of Schedules 002, 003, 011, 012, 072, 073, and 077
Secondary: Demand Metered General Service, Large General Service taken at Secondary voltage and Pumping Service
Entire Schedules 022, 031, 074, 075, 076, and 078
Demand Metered sub-set of Schedules 002, 003, 011, 012, 072, 073 and 077
Secondary subset of Schedule 021
Primary: Large General Service taken at Primary voltage, Extra Large General Service, and Special Contract
Entire Schedules 008, and 025
Primary subset of Schedule 021
Directly Assigned portion of Schedule 028
Transmission: Special Contract
At the present no Idaho customers take service at transmission level
Wwp 2/4/98
ALBIONUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$67,259 $67,259
Generation Demand $$15,926 $15,926
Transmission Demand $$18,308 $18,308
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$101,493 $0 $0 $0 $101,493
Total Power Costs$$101,493 $0 $0 $0 $101,493
Transmission $$0
Distribution Facilities $$55,669 $55,669
Metering $$971 $971
Meter Reading $$377 $377
Billing $$3,964 $3,964
Uncollectible Accounts $$512 $512
Other Customer Services $$0
Total Non-Generation$61,493 $0 $0 $0 $61,493
Load at Customer Level MWH 2,863 0 0 0 2,863
Billing Demand kW 0
Average No. of Customers No.172 172
Currently Served by Schedules No.Residential
Albion 2/4/98
CITY OF BONNERS FERRYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$53,332 $24,931 $18,692 $96,955
Energy Related Costs $$76,151 $50,549 $47,926 $174,626
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$129,483 $75,480 $66,618 $0 $271,581
Purchased Power Energy $$393,493 $261,199 $247,645 $902,337
Generation Demand $$131,361 $86,337 $64,731 $282,429
Transmission Demand $$143,741 $42,263 $31,687 $217,691
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$668,595 $389,799 $344,063 $0 $1,402,457
Total Power Costs$$798,078 $465,279 $410,681 $0 $1,674,038
Transmission $$0
Distribution Facilities $$814,453 $186,217 $114,980 $1,115,650
Metering $$19,403 $7,247 $812 $27,462
Meter Reading $$14,252 $1,863 $64 $16,179
Billing $$88,790 $11,206 $3,066 $103,062
Uncoll. Accounts Incl. in Billing
Other Customer Services $$11,178 $1,623 $0 $12,801
Total Non-Generation$948,076 $208,156 $118,922 $0 $1,275,154
Load at Customer Level MWH 28,820 19,280 18,280 0 66,380
Billing Demand kW 72,024 45,000 117,024
Average No. of Customers No.2,340 173 3 2,516
Currently Served by Schedules No.Residential Commercial Industrial
Lighting
Bonners 2/4/98
CITY OF BONNERS FERRYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.19 0.13 0.10 0.00 0.15
Energy Related Costs ¢/kWh 0.26 0.26 0.26 0.00 0.26
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.45 0.39 0.36 0.00 0.41
Purchased Power Energy ¢/kWh 1.37 1.35 1.35 0.00 1.36
Generation Demand ¢/kWh 0.46 0.45 0.35 0.00 0.43
Transmission Demand ¢/kWh 0.50 0.22 0.17 0.00 0.33
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.32 2.02 1.88 0.00 2.11
Total Power Costs¢/kWh 2.77 2.41 2.25 0.00 2.52
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 2.83 0.97 0.63 0.00 1.68
Metering ¢/kWh 0.07 0.04 0.00 0.00 0.04
Meter Reading ¢/kWh 0.05 0.01 0.00 0.00 0.02
Billing ¢/kWh 0.31 0.06 0.02 0.00 0.16
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.04 0.01 0.00 0.00 0.02
Total Non-Generation¢/kWh 3.29 1.08 0.65 0.00 1.92
Total Cost¢/kWh 6.06 3.49 2.90 0.00 4.44
Load at Customer Level MWH 28,820 19,280 18,280 0 66,380
Billing Demand kW 0 72,024 45,000 117,024
Average No. of Customers No.2,340 173 3 2,516
Currently Served by Schedules No.Residential Commercial Industrial
Lighting
Bonners 2/4/98
CITY OF BURLEYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$1,571,947 $427,396 $613,015 $2,612,358
Generation Demand $$280,756 $111,533 $69,227 $461,516
Transmission Demand $$322,829 $128,247 $79,602 $530,678
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$2,175,532 $667,176 $761,844 $0 $3,604,552
Total Power Costs$$2,175,532 $667,176 $761,844 $0 $3,604,552
Transmission $$0
Distribution Facilities $$891,727 $354,248 $219,878 $1,465,853
Metering $$65,940 $5,088 $6,080 $77,108
Meter Reading $$46,769 $464 $59 $47,292
Billing $$20,400 $464 $59 $20,923
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$43,000 $0 $0 $43,000
Total Non-Generation$1,067,836 $360,264 $226,076 $0 $1,654,176
Load at Customer Level MWH 71,538 19,650 22,080 0 113,268
Billing Demand kW 5,800 3,200 9,000
Average No. of Customers No.4,028 47 6 4,081
Currently Served by Schedules Residential 3ph Commercial 3ph Commercial
City Use
1ph Commercial
3ph Commercial
Burley 2/4/98
CITY OF BURLEYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.20 2.18 2.78 0.00 2.31
Generation Demand ¢/kWh 0.39 0.57 0.31 0.00 0.41
Transmission Demand ¢/kWh 0.45 0.65 0.36 0.00 0.47
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.04 3.40 3.45 0.00 3.18
Total Power Costs¢/kWh 3.04 3.40 3.45 0.00 3.18
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.25 1.80 1.00 0.00 1.29
Metering ¢/kWh 0.09 0.03 0.03 0.00 0.07
Meter Reading ¢/kWh 0.07 0.00 0.00 0.00 0.04
Billing ¢/kWh 0.03 0.00 0.00 0.00 0.02
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.06 0.00 0.00 0.00 0.04
Total Non-Generation¢/kWh 1.49 1.83 1.02 0.00 1.46
Total Cost¢/kWh 4.53 5.23 4.47 0.00 4.64
Load at Customer Level MWH 71,538 19,650 22,080 0 113,268
Billing Demand kW 0 5,800 3,200 9,000
Average No. of Customers No.4,028 47 6 4,081
Currently Served by Schedules Residential 3ph Commercial 3ph Commercial
City Use
1ph Commercial
3ph Commercial
Burley 2/4/98
CLEARWATER POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$16,449 $2,514 $18,963
Total Generation $$16,449 $2,514 $0 $0 $18,963
Purchased Power Energy $$2,616,978 $399,750 $3,016,728
Generation Demand $$498,459 $101,050 $599,509
Transmission Demand $$659,509 $136,094 $795,603
Load Shaping $$0 $0 $0
Load Regulation $$0 $0 $0
Total Purchased Power $$3,774,946 $636,894 $0 $0 $4,411,840
Total Power Costs$$3,791,395 $639,408 $0 $0 $4,430,803
Transmission $$80,966 $10,138 $91,104
Distribution Facilities $$6,831,126 $493,200 $7,324,326
Metering $$58,012 $1,948 $59,960
Meter Reading $$57,111 $1,213 $58,324
Billing $$234,987 $5,238 $240,225
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0 $0 $0
Total Non-Generation$7,262,202 $511,737 $0 $0 $7,773,939
Load at Customer Level MWH 123,238 18,690 0 0 141,928
Billing Demand kW 72,294 72,294
Average No. of Customers No.8,360 109 8,469
Currently Served by Schedules No.Farm-Home Irrigation
Residential Large Comm.
Small Comm.
Lighting
Clearwater Power filed their Primary data confidential so it is not shown on this report but included in the composite.
ClearWtr 2/27/98
CLEARWATER POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.01 0.01 0.00 0.00 0.01
Total Generation ¢/kWh 0.01 0.01 0.00 0.00 0.01
Purchased Power Energy ¢/kWh 2.12 2.14 0.00 0.00 2.13
Generation Demand ¢/kWh 0.40 0.54 0.00 0.00 0.42
Transmission Demand ¢/kWh 0.54 0.73 0.00 0.00 0.56
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.06 3.41 0.00 0.00 3.11
Total Power Costs¢/kWh 3.08 3.42 0.00 0.00 3.12
Transmission ¢/kWh 0.07 0.05 0.00 0.00 0.06
Distribution Facilities ¢/kWh 5.54 2.64 0.00 0.00 5.16
Metering ¢/kWh 0.05 0.01 0.00 0.00 0.04
Meter Reading ¢/kWh 0.05 0.01 0.00 0.00 0.04
Billing ¢/kWh 0.19 0.03 0.00 0.00 0.17
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 5.89 2.74 0.00 0.00 5.48
Total Cost¢/kWh 8.97 6.16 0.00 0.00 8.60
Load at Customer Level MWH 123,238 18,690 0 0 141,928
Billing Demand kW 0 72,294 72,294
Average No. of Customers No.8,360 109 8,469
Currently Served by Schedules No.Farm-Home Irrigation
Residential Large Comm.
Small Comm.
Lighting
Clearwater Power filed their Primary data confidential so it is not shown on this report but included in the composite.
ClearWtr 2/27/98
CITY OF DECLOUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$64,013 $64,013
Generation Demand $$13,929 $13,929
Transmission Demand $$15,980 $15,980
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$93,922 $0 $0 $0 $93,922
Total Power Costs$$93,922 $0 $0 $0 $93,922
Transmission $$0
Distribution Facilities $$29,629 $29,629
Metering $$688 $688
Meter Reading $$319 $319
Billing $$2,032 $2,032
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$263 $263
Total Non-Generation$32,931 $0 $0 $0 $32,931
Load at Customer Level MWH 2,650 0 0 0 2,650
Billing Demand kW 0
Average No. of Customers No.107 107
Currently Served by Schedules No.Residential
Declo 2/4/98
CITY OF DECLOUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.42 0.00 0.00 0.00 2.42
Generation Demand ¢/kWh 0.53 0.00 0.00 0.00 0.53
Transmission Demand ¢/kWh 0.60 0.00 0.00 0.00 0.60
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.54 0.00 0.00 0.00 3.54
Total Power Costs¢/kWh 3.54 0.00 0.00 0.00 3.54
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.12 0.00 0.00 0.00 1.12
Metering ¢/kWh 0.03 0.00 0.00 0.00 0.03
Meter Reading ¢/kWh 0.01 0.00 0.00 0.00 0.01
Billing ¢/kWh 0.08 0.00 0.00 0.00 0.08
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.01 0.00 0.00 0.00 0.01
Total Non-Generation¢/kWh 1.24 0.00 0.00 0.00 1.24
Total Cost¢/kWh 4.79 0.00 0.00 0.00 4.79
Load at Customer Level MWH 2,650 0 0 0 2,650
Billing Demand kW 0
Average No. of Customers No.107 107
Currently Served by Schedules No.Residential
Declo 2/4/98
FALL RIVER RURAL ELECTRICUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$365,280 $296,275 $661,555
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$5,833 $5,172 $11,005
Total Generation $$371,113 $301,447 $0 $0 $672,560
Purchased Power Energy $$1,824,045 $1,602,925 $3,426,970
Generation Demand $$273,848 $346,240 $620,088
Transmission Demand $$250,595 $325,062 $575,657
Load Shaping $$0 $0 $0
Load Regulation $$0 $0 $0
Total Purchased Power $$2,348,488 $2,274,227 $0 $0 $4,622,715
Total Power Costs$$2,719,601 $2,575,674 $0 $0 $5,295,275
Transmission $$81,246 $47,720 $128,966
Distribution Facilities $$2,806,584 $2,000,597 $4,807,181
Metering $$66,169 $47,847 $114,016
Meter Reading $$69,537 $28,624 $98,161
Billing $$146,817 $60,436 $207,253
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0 $0 $0
Total Non-Generation$3,170,353 $2,185,224 $0 $0 $5,355,577
Load at Customer Level MWH 85,992 92,105 0 0 178,097
Billing Demand kW 320,421 320,421
Average No. of Customers No.7,887 1,599 9,486
Currently Served by Schedules No.Farm-Home Irrigation
Residential Large Comm.
Small Comm.
Lighting
FallRivr 2/27/98
FALL RIVER RURAL ELECTRICUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.42 0.32 0.00 0.00 0.37
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.01 0.01 0.00 0.00 0.01
Total Generation ¢/kWh 0.43 0.33 0.00 0.00 0.38
Purchased Power Energy ¢/kWh 2.12 1.74 0.00 0.00 1.92
Generation Demand ¢/kWh 0.32 0.38 0.00 0.00 0.35
Transmission Demand ¢/kWh 0.29 0.35 0.00 0.00 0.32
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.73 2.47 0.00 0.00 2.60
Total Power Costs¢/kWh 3.16 2.80 0.00 0.00 2.97
Transmission ¢/kWh 0.09 0.05 0.00 0.00 0.07
Distribution Facilities ¢/kWh 3.26 2.17 0.00 0.00 2.70
Metering ¢/kWh 0.08 0.05 0.00 0.00 0.06
Meter Reading ¢/kWh 0.08 0.03 0.00 0.00 0.06
Billing ¢/kWh 0.17 0.07 0.00 0.00 0.12
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 3.69 2.37 0.00 0.00 3.01
Total Cost¢/kWh 6.85 5.17 0.00 0.00 5.98
Load at Customer Level MWH 85,992 92,105 0 0 178,097
Billing Demand kW 320,421 320,421
Average No. of Customers No.7,887 1,599 9,486
Currently Served by Schedules No.Farm-Home Irrigation
Residential Large Comm.
Small Comm.
Lighting
FallRivr 2/27/98
CITY OF HEYBURNUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$417,528 $25,334 $1,788,199 $2,231,061
Generation Demand $$18,082 $8,603 $133,622 $160,307
Transmission Demand $$47,578 $22,635 $351,589 $421,802
Load Shaping $$3,932 $1,870 $29,054 $34,856
Load Regulation $$3,447 $1,640 $25,470 $30,557
Total Purchased Power $$490,567 $60,082 $2,327,934 $0 $2,878,583
Total Power Costs$$490,567 $60,082 $2,327,934 $0 $2,878,583
Transmission $$0
Distribution Facilities $$463,275 $13,050 $2,610 $478,935
Metering $$13,440 $379 $76 $13,895
Meter Reading $$27,765 $782 $156 $28,703
Billing $$38,447 $1,083 $217 $39,747
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$542,927 $15,294 $3,059 $0 $561,280
Load at Customer Level MWH 20,376 1,143 86,568 0 108,087
Billing Demand kW 1,030 13,473 14,503
Average No. of Customers No.1,065 30 6 1,101
Currently Served by Schedules No.Residential Commercial Commercial
Commercial Industrial
Lighting
Heyburn 2/4/98
CITY OF HEYBURNUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.05 2.22 2.07 0.00 2.06
Generation Demand ¢/kWh 0.09 0.75 0.15 0.00 0.15
Transmission Demand ¢/kWh 0.23 1.98 0.41 0.00 0.39
Load Shaping ¢/kWh 0.02 0.16 0.03 0.00 0.03
Load Regulation ¢/kWh 0.02 0.14 0.03 0.00 0.03
Total Purchased Power ¢/kWh 2.41 5.26 2.69 0.00 2.66
Total Power Costs¢/kWh 2.41 5.26 2.69 0.00 2.66
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 2.27 1.14 0.00 0.00 0.44
Metering ¢/kWh 0.07 0.03 0.00 0.00 0.01
Meter Reading ¢/kWh 0.14 0.07 0.00 0.00 0.03
Billing ¢/kWh 0.19 0.09 0.00 0.00 0.04
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.66 1.34 0.00 0.00 0.52
Total Cost¢/kWh 5.07 6.59 2.69 0.00 3.18
Load at Customer Level MWH 20,376 1,143 86,568 0 108,087
Billing Demand kW 1,030 13,473 14,503
Average No. of Customers No.1,065 30 6 1,101
Currently Served by Schedules Residential Commercial Commercial
Commercial Industrial
Lighting
Heyburn 2/4/98
IDAHO COUNTY LIGHT AND POWERUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$51,000 $51,000
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$51,000 $0 $0 $0 $51,000
Purchased Power Energy $$810,000 $86,000 $896,000
Generation Demand $$75,000 $11,000 $86,000
Transmission Demand $$178,000 $27,000 $205,000
Load Shaping $$13,000 $2,000 $15,000
Load Regulation $$1,000 $1,000
Total Purchased Power $$1,077,000 $126,000 $0 $0 $1,203,000
Total Power Costs$$1,128,000 $126,000 $0 $0 $1,254,000
Transmission $$0
Distribution Facilities $$1,419,000 $80,000 $1,499,000
Metering $$28,000 $1,000 $29,000
Meter Reading $$37,000 $2,000 $39,000
Billing $$106,000 $7,000 $113,000
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$27,000 $1,000 $28,000
Total Non-Generation$1,617,000 $91,000 $0 $0 $1,708,000
Load at Customer Level MWH 35,641 3,810 0 0 39,451
Billing Demand kW 12,308 12,308
Average No. of Customers No.2,620 33 2,653
Currently Served by Schedules No.Residential Irrigation
General Large Power
IdaCnty 2/4/98
IDAHO COUNTY LIGHT AND POWERUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.14 0.00 0.00 0.00 0.13
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.14 0.00 0.00 0.00 0.13
Purchased Power Energy ¢/kWh 2.27 2.26 0.00 0.00 2.27
Generation Demand ¢/kWh 0.21 0.29 0.00 0.00 0.22
Transmission Demand ¢/kWh 0.50 0.71 0.00 0.00 0.52
Load Shaping ¢/kWh 0.04 0.05 0.00 0.00 0.04
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.02 3.31 0.00 0.00 3.05
Total Power Costs¢/kWh 3.16 3.31 0.00 0.00 3.18
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 3.98 2.10 0.00 0.00 3.80
Metering ¢/kWh 0.08 0.03 0.00 0.00 0.07
Meter Reading ¢/kWh 0.10 0.05 0.00 0.00 0.10
Billing ¢/kWh 0.30 0.18 0.00 0.00 0.29
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.08 0.03 0.00 0.00 0.07
Total Non-Generation¢/kWh 4.54 2.39 0.00 0.00 4.33
Total Cost¢/kWh 7.70 5.70 0.00 0.00 7.51
Load at Customer Level MWH 35,641 3,810 0 0 39,451
Billing Demand kW 12,308 12,308
Average No. of Customers No.2,620 33 2,653
Currently Served by Schedules No.Residential Irrigation
General Large Power
IdaCnty 2/4/98
CITY OF IDAHO FALLSUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$172,723 $172,723
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$172,723 $0 $0 $0 $172,723
Purchased Power Energy $$6,977,274 $5,152,928 $988,694 $13,118,896
Generation Demand $$989,026 $1,247,360 $132,496 $2,368,882
Transmission Demand $$1,048,214 $1,322,008 $140,425 $2,510,647
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$9,014,514 $7,722,296 $1,261,615 $0 $17,998,425
Total Power Costs$$9,187,237 $7,722,296 $1,261,615 $0 $18,171,148
Transmission $$0
Distribution Facilities $$5,479,531 $3,236,542 $243,865 $8,959,938
Metering $$108,312 $83,088 $4,257 $195,657
Meter Reading $$246,492 $53,741 $235 $300,468
Billing $$449,110 $43,518 $95 $492,723
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$205,169 $22,366 $0 $227,535
Total Non-Generation$6,488,614 $3,439,255 $248,452 $0 $10,176,321
Load at Customer Level MWH 319,555 236,001 45,282 0 600,838
Billing Demand kW 72,349 7,685 80,034
Average No. of Customers No.18,920 2,750 6 21,676
Currently Served by Schedules Residential Commercial Industrial
IdahoFls 2/13/98
CITY OF IDAHO FALLSUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.05 0.00 0.00 0.00 0.03
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.05 0.00 0.00 0.00 0.03
Purchased Power Energy ¢/kWh 2.18 2.18 2.18 0.00 2.18
Generation Demand ¢/kWh 0.31 0.53 0.29 0.00 0.39
Transmission Demand ¢/kWh 0.33 0.56 0.31 0.00 0.42
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.82 3.27 2.79 0.00 3.00
Total Power Costs¢/kWh 2.88 3.27 2.79 0.00 3.02
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.71 1.37 0.54 0.00 1.49
Metering ¢/kWh 0.03 0.04 0.01 0.00 0.03
Meter Reading ¢/kWh 0.08 0.02 0.00 0.00 0.05
Billing ¢/kWh 0.14 0.02 0.00 0.00 0.08
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.06 0.01 0.00 0.00 0.04
Total Non-Generation¢/kWh 2.03 1.46 0.55 0.00 1.69
Total Cost¢/kWh 4.91 4.73 3.33 0.00 4.72
Load at Customer Level MWH 319,555 236,001 45,282 0 600,838
Billing Demand kW 72,349 7,685 80,034
Average No. of Customers No.18,920 2,750 6 21,676
Currently Served by Schedules Residential Commercial Industrial
IdahoFls 2/13/98
LOST RIVER ELECTRIC CO-OPUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$4,058 $5,113 $9,171
Total Generation $$4,058 $5,113 $0 $0 $9,171
Purchased Power Energy $$442,225 $557,193 $999,418
Generation Demand $$109,752 $124,796 $234,548
Transmission Demand $$127,447 $144,917 $272,364
Load Shaping $$0 $0 $0
Load Regulation $$0 $0 $0
Total Purchased Power $$679,424 $826,906 $0 $0 $1,506,330
Total Power Costs$$683,482 $832,019 $0 $0 $1,515,501
Transmission $$2,615 $3,126 $5,741
Distribution Facilities $$557,566 $732,769 $1,290,335
Metering $$13,542 $29,331 $42,873
Meter Reading $$31,330 $13,394 $44,724
Billing $$41,130 $31,197 $72,327
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$4,783 $3,628 $8,411
Total Non-Generation$650,966 $813,445 $0 $0 $1,464,411
Load at Customer Level MWH 24,725 38,641 0 0 63,366
Billing Demand kW 74,138 74,138
Average No. of Customers No.1,642 702 2,344
Currently Served by Schedules Residential Irrigation
Lighting Large Comm.
Lostrivr 2/27/98
LOST RIVER ELECTRIC CO-OPUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.02 0.01 0.00 0.00 0.01
Total Generation ¢/kWh 0.02 0.01 0.00 0.00 0.01
Purchased Power Energy ¢/kWh 1.79 1.44 0.00 0.00 1.58
Generation Demand ¢/kWh 0.44 0.32 0.00 0.00 0.37
Transmission Demand ¢/kWh 0.52 0.38 0.00 0.00 0.43
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.75 2.14 0.00 0.00 2.38
Total Power Costs¢/kWh 2.76 2.15 0.00 0.00 2.39
Transmission ¢/kWh 0.01 0.01 0.00 0.00 0.01
Distribution Facilities ¢/kWh 2.26 1.90 0.00 0.00 2.04
Metering ¢/kWh 0.05 0.08 0.00 0.00 0.07
Meter Reading ¢/kWh 0.13 0.03 0.00 0.00 0.07
Billing ¢/kWh 0.17 0.08 0.00 0.00 0.11
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.02 0.01 0.00 0.00 0.01
Total Non-Generation¢/kWh 2.63 2.11 0.00 0.00 2.31
Total Cost¢/kWh 5.40 4.26 0.00 0.00 4.70
Load at Customer Level MWH 24,725 38,641 0 0 63,366
Billing Demand kW 74,138 74,138
Average No. of Customers No.1,642 702 2,344
Currently Served by Schedules Residential Irrigation
Lighting Large Comm.
Lostrivr 2/27/98
LOWER VALLEY POWER AND LIGHTUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$28,100 $8,042 $2,447 $38,589
Energy Related Costs $$114,852 $32,869 $10,000 $157,721
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$646,381 $184,984 $56,276 $887,641
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$789,333 $225,895 $68,723 $0 $1,083,951
Purchased Power Energy $$0
Generation Demand $$0
Transmission Demand $$0
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$0 $0 $0 $0 $0
Total Power Costs$$789,333 $225,895 $68,723 $0 $1,083,951
Transmission $$1,556,807 $445,535 $135,542 $2,137,884
Distribution Facilities $$6,362,095 $1,820,737 $553,909 $8,736,741
Metering $$0
Meter Reading $$356,396 $101,995 $31,029 $489,420
Billing $$594,156 $170,039 $51,370 $815,565
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$8,869,454 $2,538,306 $771,850 $0 $12,179,610
Load at Customer Level MWH 337,406 108,326 41,994 0 487,726
Billing Demand kW 42,480 8,987 51,467
Average No. of Customers No.16,855 293 1 17,149
Currently Served by Schedules No.R1, R3, C1, I1,C2 C3
L1
Lower Valley filed their power cost data confidentially so it is removed from this spreadsheet but remains in the Consumer-Owned
Utility totals.
LowerVly 2/4/98
LOWER VALLEY POWER AND LIGHTUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.01 0.01 0.01 0.00 0.01
Energy Related Costs ¢/kWh 0.03 0.03 0.02 0.00 0.03
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.19 0.17 0.13 0.00 0.18
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.23 0.21 0.16 0.00 0.22
Purchased Power Energy ¢/kWh 0.00 0.00 0.00 0.00 0.00
Generation Demand ¢/kWh 0.00 0.00 0.00 0.00 0.00
Transmission Demand ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Power Costs¢/kWh 0.23 0.21 0.16 0.00 0.22
Transmission ¢/kWh 0.46 0.41 0.32 0.00 0.44
Distribution Facilities ¢/kWh 1.89 1.68 1.32 0.00 1.79
Metering ¢/kWh 0.00 0.00 0.00 0.00 0.00
Meter Reading ¢/kWh 0.11 0.09 0.07 0.00 0.10
Billing ¢/kWh 0.18 0.16 0.12 0.00 0.17
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.63 2.34 1.84 0.00 2.50
Total Cost¢/kWh 2.86 2.55 2.00 0.00 2.72
Load at Customer Level MWH 337,406 108,326 41,994 0 487,726
Billing Demand kW 0 42,480 8,987 51,467
Average No. of Customers No.16,855 293 1 17,149
Currently Served by Schedules No.R1, R3, C1, I1,C2 C3
L1
Lower Valley filed their power cost data confidentially so it is removed from this spreadsheet but remains in the Consumer-Owned
Utility totals.
LowerVly 2/4/98
SCHEDULE NO.TITLE OF SCHEDULER1 Residential
R3 Residential
C1 Small Commercial
C2 Large Commercial
C3 Industrial
I1 Irrigation
L1 Lighting
LOWER VALLEY POWER AND LIGHT
NORTHERN LIGHTS, INC.UNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$137,581 $42,680 $19,739 $200,000
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$137,581 $42,680 $19,739 $0 $200,000
Purchased Power Energy $$2,997,807 $929,958 $430,185 $4,357,950
Generation Demand $$1,207,769 $355,766 $130,575 $1,694,110
Transmission Demand $$175,527 $51,903 $24,174 $251,604
Load Shaping $$11,118 $3,914 $1,777 $16,809
Load Regulation $$9,729 $3,425 $1,555 $14,709
Total Purchased Power $$4,401,950 $1,344,966 $588,266 $0 $6,335,182
Total Power Costs$$4,539,531 $1,387,646 $608,005 $0 $6,535,182
Transmission $$3,579 $988 $433 $5,000
Distribution Facilities $$7,922,260 $2,146,171 $851,289 $10,919,720
Metering $$77,252 $13,671 $77 $91,000
Meter Reading $$165,713 $8,030 $52 $173,795
Billing $$801,544 $40,554 $387 $842,485
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$179,873 $48,969 $19,447 $248,289
Total Non-Generation$9,150,221 $2,258,383 $871,685 $0 $12,280,289
Load at Customer Level MWH 146,142 45,304 21,050 0 212,496
Billing Demand kW 116,516 45,322 161,838
Average No. of Customers No.12,630 612 4 13,246
Currently Served by Schedules Residential Commercial Industrial
Seasonal Industrial
Irrigation
Northern 2/4/98
NORTHERN LIGHTS, INC.UNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$157,115 $23,146 $19,739 $200,000
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$157,115 $23,146 $19,739 $0 $200,000
Purchased Power Energy $$3,455,152 $509,018 $434,075 $4,398,245
Generation Demand $$634,650 $117,141 $78,710 $830,501
Transmission Demand $$796,313 $146,980 $98,760 $1,042,053
Load Shaping $$0 $0 $0 $0
Load Regulation $$0 $0 $0 $0
Total Purchased Power $$4,886,115 $773,139 $611,545 $0 $6,270,799
Total Power Costs$$5,043,230 $796,285 $631,284 $0 $6,470,799
Transmission $$3,915 $652 $433 $5,000
Distribution Facilities $$5,449,070 $836,955 $538,280 $6,824,305
Metering $$89,609 $1,314 $77 $91,000
Meter Reading $$172,011 $1,732 $52 $173,795
Billing $$647,156 $6,228 $300 $653,684
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$186,914 $1,799 $87 $188,800
Total Non-Generation$6,548,675 $848,680 $539,229 $0 $7,936,584
Load at Customer Level MWH 146,142 45,304 21,050 0 212,496
Billing Demand kW 116,516 45,322 161,838
Average No. of Customers No.12,630 612 4 13,246
Currently Served by Schedules Residential Commercial Industrial
Seasonal Industrial
Irrigation
North 2/27/98
NORTHERN LIGHTS, INC.UNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.11 0.05 0.09 0.00 0.09
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.11 0.05 0.09 0.00 0.09
Purchased Power Energy ¢/kWh 2.36 1.12 2.06 0.00 2.07
Generation Demand ¢/kWh 0.43 0.26 0.37 0.00 0.39
Transmission Demand ¢/kWh 0.54 0.32 0.47 0.00 0.49
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.34 1.71 2.91 0.00 2.95
Total Power Costs¢/kWh 3.45 1.76 3.00 0.00 3.05
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 3.73 1.85 2.56 0.00 3.21
Metering ¢/kWh 0.06 0.00 0.00 0.00 0.04
Meter Reading ¢/kWh 0.12 0.00 0.00 0.00 0.08
Billing ¢/kWh 0.44 0.01 0.00 0.00 0.31
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.13 0.00 0.00 0.00 0.09
Total Non-Generation¢/kWh 4.48 1.87 2.56 0.00 3.73
Total Cost¢/kWh 7.93 3.63 5.56 0.00 6.78
Load at Customer Level MWH 146,142 45,304 21,050 0 212,496
Billing Demand kW 116,516 45,322 161,838
Average No. of Customers No.12,630 612 4 13,246
Currently Served by Schedules Residential Commercial Industrial
Seasonal Industrial
Irrigation
North 2/27/98
CITY OF PLUMMERUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.07 2.30 2.49 0.00 2.30
Generation Demand ¢/kWh 0.35 0.16 0.08 0.00 0.20
Transmission Demand ¢/kWh 1.02 0.46 0.24 0.00 0.57
Load Shaping ¢/kWh 0.06 0.03 0.01 0.00 0.03
Load Regulation ¢/kWh 0.07 0.03 0.02 0.00 0.04
Total Purchased Power ¢/kWh 3.57 2.98 2.84 0.00 3.14
Total Power Costs¢/kWh 3.57 2.98 2.84 0.00 3.14
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.48 0.35 0.72 0.00 0.96
Metering ¢/kWh 0.19 0.04 0.01 0.00 0.08
Meter Reading ¢/kWh 0.12 0.02 0.00 0.00 0.05
Billing ¢/kWh 0.27 0.03 0.00 0.00 0.11
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.06 0.44 0.74 0.00 1.20
Total Cost¢/kWh 5.64 3.42 3.57 0.00 4.34
Load at Customer Level MWH 10,934 4,060 13,425 0 28,419
Billing Demand kW 577 987 1,564
Average No. of Customers No.732 29 3 764
Currently Served by Schedules Residential Commercial Industrial
Commercial
Plummer 2/4/98
RAFT RIVER RURAL ELECTRIC CO-OPUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$46,432 $46,432
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$26,282 $26,282
Total Generation $$0 $72,714 $0 $0 $72,714
Purchased Power Energy $$25,429 $3,590,033 $3,615,462
Generation Demand $$9,359 $818,891 $828,250
Transmission Demand $$8,836 $773,171 $782,007
Load Shaping $$67 $5,900 $5,967
Load Regulation $$59 $5,162 $5,221
Total Purchased Power $$43,750 $5,193,157 $0 $0 $5,236,907
Total Power Costs$$43,750 $5,265,871 $0 $0 $5,309,621
Transmission $$7,753 $362,274 $370,027
Distribution Facilities $$89,409 $2,137,615 $2,227,024
Metering $$2,512 $121,844 $124,356
Meter Reading $$516 $67,599 $68,115
Billing $$4,445 $73,440 $77,885
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$3,877 $102,334 $106,211
Total Non-Generation$108,512 $2,865,106 $0 $0 $2,973,618
Load at Customer Level MWH 1,368 193,125 0 0 194,493
Billing Demand kW 495,379 495,379
Average No. of Customers No.243 2,290 2,533
Currently Served by Schedules Residential Residential
Commercial
Irrigation
RaftRivr 2/4/98
RAFT RIVER RURAL ELECTRIC CO-OPUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.02 0.00 0.00 0.02
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.01 0.00 0.00 0.01
Total Generation ¢/kWh 0.00 0.04 0.00 0.00 0.04
Purchased Power Energy ¢/kWh 1.86 1.86 0.00 0.00 1.86
Generation Demand ¢/kWh 0.68 0.42 0.00 0.00 0.43
Transmission Demand ¢/kWh 0.65 0.40 0.00 0.00 0.40
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.20 2.69 0.00 0.00 2.69
Total Power Costs¢/kWh 3.20 2.73 0.00 0.00 2.73
Transmission ¢/kWh 0.57 0.19 0.00 0.00 0.19
Distribution Facilities ¢/kWh 6.54 1.11 0.00 0.00 1.15
Metering ¢/kWh 0.18 0.06 0.00 0.00 0.06
Meter Reading ¢/kWh 0.04 0.04 0.00 0.00 0.04
Billing ¢/kWh 0.32 0.04 0.00 0.00 0.04
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.28 0.05 0.00 0.00 0.05
Total Non-Generation¢/kWh 7.93 1.48 0.00 0.00 1.53
Total Cost¢/kWh 11.13 4.21 0.00 0.00 4.26
Load at Customer Level MWH 1,368 193,125 0 0 194,493
Billing Demand kW 495,379 495,379
Average No. of Customers No.243 2,290 2,533
Currently Served by Schedules Residential Residential
Commercial
Irrigation
RaftRivr 2/4/98
CITY OF RUPERTUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$983,225 $718,500 $1,701,725
Generation Demand $$248,305 $119,432 $367,737
Transmission Demand $$284,554 $136,868 $421,422
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$1,516,084 $974,800 $0 $0 $2,490,884
Total Power Costs$$1,516,084 $974,800 $0 $0 $2,490,884
Transmission $$0
Distribution Facilities $$1,061,587 $172,184 $1,233,771
Metering $$63,400 $6,855 $70,255
Meter Reading $$30,211 $6,533 $36,744
Billing $$73,864 $7,987 $81,851
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$1,229,062 $193,559 $0 $0 $1,422,621
Load at Customer Level MWH 43,329 31,663 0 0 74,992
Billing Demand kW 4,959 4,959
Average No. of Customers No.2,497 270 2,767
Currently Served by Schedules No.1, 4, 5, 6, 7, 9 2, 3
Rupert 2/4/98
CITY OF RUPERTUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.27 2.27 0.00 0.00 2.27
Generation Demand ¢/kWh 0.57 0.38 0.00 0.00 0.49
Transmission Demand ¢/kWh 0.66 0.43 0.00 0.00 0.56
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.50 3.08 0.00 0.00 3.32
Total Power Costs¢/kWh 3.50 3.08 0.00 0.00 3.32
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 2.45 0.54 0.00 0.00 1.65
Metering ¢/kWh 0.15 0.02 0.00 0.00 0.09
Meter Reading ¢/kWh 0.07 0.02 0.00 0.00 0.05
Billing ¢/kWh 0.17 0.03 0.00 0.00 0.11
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.84 0.61 0.00 0.00 1.90
Total Cost¢/kWh 6.34 3.69 0.00 0.00 5.22
Load at Customer Level MWH 43,329 31,663 0 0 74,992
Billing Demand kW 4,959 4,959
Average No. of Customers No.2,497 270 2,767
Currently Served by Schedules No.1, 4, 5, 6, 7, 9 2, 3
Rupert 2/4/98
RURAL ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$944,982 $806,076 $1,751,058
Generation Demand $$197,025 $188,489 $385,514
Transmission Demand $$225,776 $215,990 $441,766
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$1,367,783 $1,210,555 $0 $0 $2,578,338
Total Power Costs$$1,367,783 $1,210,555 $0 $0 $2,578,338
Transmission $$0
Distribution Facilities $$602,118 $694,282 $1,296,400
Metering $$43,373 $16,627 $60,000
Meter Reading $$26,197 $10,143 $36,340
Billing $$91,331 $35,011 $126,342
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$763,019 $756,063 $0 $0 $1,519,082
Load at Customer Level MWH 46,191 47,388 0 0 93,579
Billing Demand kW 96,818 96,818
Average No. of Customers No.2,113 810 2,923
Currently Served by Schedules Residential Commercial
Irrigation
Rural 2/4/98
RURAL ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.05 1.70 0.00 0.00 1.87
Generation Demand ¢/kWh 0.43 0.40 0.00 0.00 0.41
Transmission Demand ¢/kWh 0.49 0.46 0.00 0.00 0.47
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.96 2.55 0.00 0.00 2.76
Total Power Costs¢/kWh 2.96 2.55 0.00 0.00 2.76
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.30 1.47 0.00 0.00 1.39
Metering ¢/kWh 0.09 0.04 0.00 0.00 0.06
Meter Reading ¢/kWh 0.06 0.02 0.00 0.00 0.04
Billing ¢/kWh 0.20 0.07 0.00 0.00 0.14
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 1.65 1.60 0.00 0.00 1.62
Total Cost¢/kWh 4.61 4.15 0.00 0.00 4.38
Load at Customer Level MWH 46,191 47,388 0 0 93,579
Billing Demand kW 0 96,818 96,818
Average No. of Customers No.2,113 810 2,923
Currently Served by Schedules Residential Commercial
Irrigation
Rural 2/4/98
SALMON RIVER ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$7,000 $7,000
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$7,000 $0 $0 $0 $7,000
Purchased Power Energy $$733,762 $412,436 $1,146,198
Generation Demand $$104,267 $77,153 $181,420
Transmission Demand $$137,178 $101,506 $238,684
Load Shaping $$2,985 $2,209 $5,194
Load Regulation $$2,613 $1,932 $4,545
Total Purchased Power $$980,805 $595,236 $0 $0 $1,576,041
Total Power Costs$$987,805 $595,236 $0 $0 $1,583,041
Transmission $$0
Distribution Facilities $$899,666 $145,740 $1,045,406
Metering $$18,538 $12,527 $31,065
Meter Reading $$9,682 $18,647 $28,329
Billing $$71,978 $30,660 $102,638
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$43,851 $10,054 $53,905
Total Non-Generation$1,043,715 $217,628 $0 $0 $1,261,343
Load at Customer Level MWH 34,176 19,210 0 0 53,386
Billing Demand kW 41,472 41,472
Average No. of Customers No.2,236 246 2,482
Currently Served by Schedules No.A, B, D, E B, C, D
Salmon River filed their Primary data confidential so it is removed from this report but included in the composite.
Salmonr 2/4/98
SALMON RIVER ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.02 0.00 0.00 0.00 0.01
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.02 0.00 0.00 0.00 0.01
Purchased Power Energy ¢/kWh 2.15 2.15 0.00 0.00 2.15
Generation Demand ¢/kWh 0.31 0.40 0.00 0.00 0.34
Transmission Demand ¢/kWh 0.40 0.53 0.00 0.00 0.45
Load Shaping ¢/kWh 0.01 0.01 0.00 0.00 0.01
Load Regulation ¢/kWh 0.01 0.01 0.00 0.00 0.01
Total Purchased Power ¢/kWh 2.87 3.10 0.00 0.00 2.95
Total Power Costs¢/kWh 2.89 3.10 0.00 0.00 2.97
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 2.63 0.76 0.00 0.00 1.96
Metering ¢/kWh 0.05 0.07 0.00 0.00 0.06
Meter Reading ¢/kWh 0.03 0.10 0.00 0.00 0.05
Billing ¢/kWh 0.21 0.16 0.00 0.00 0.19
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.13 0.05 0.00 0.00 0.10
Total Non-Generation¢/kWh 3.05 1.13 0.00 0.00 2.36
Total Cost¢/kWh 5.94 4.23 0.00 0.00 5.33
Load at Customer Level MWH 34,176 19,210 0 0 53,386
Billing Demand kW 41,472 0 0 41,472
Average No. of Customers No.2,236 246 0 0 2,482
Currently Served by Schedules No.A, B, D, E B, C, D
Salmon River filed their Primary data confidential so it is removed from this report but included in the composite.
Salmonr 2/4/98
SOUTH SIDE ELECTRIC LINESUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$764,637 $681,747 $1,446,384
Generation Demand $$204,267 $217,085 $421,352
Transmission Demand $$160,945 $171,045 $331,990
Load Shaping $$6,941 $7,376 $14,317
Load Regulation $$6,073 $6,454 $12,527
Total Purchased Power $$1,142,863 $1,083,707 $0 $0 $2,226,570
Total Power Costs$$1,142,863 $1,083,707 $0 $0 $2,226,570
Transmission $$0
Distribution Facilities $$596,308 $335,424 $931,732
Metering $$22,928 $34,391 $57,319
Meter Reading $$9,672 $34,080 $43,752
Billing $$7,623 $4,477 $12,100
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$169,495 $99,545 $269,040
Total Non-Generation$806,026 $507,917 $0 $0 $1,313,943
Load at Customer Level MWH 19,425 21,875 0 0 41,300
Billing Demand kW 66,583 66,583
Average No. of Customers No.672 247 919
Currently Served by Schedules Residential Irrigation
SSide 2/4/98
CITY OF SODA SPRINGSUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$58,433 $24,545 $82,978
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$58,433 $24,545 $0 $0 $82,978
Purchased Power Energy $$391,249 $156,282 $547,531
Generation Demand $$68,008 $26,343 $94,351
Transmission Demand $$77,936 $30,189 $108,125
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$537,193 $212,814 $0 $0 $750,007
Total Power Costs$$595,626 $237,359 $0 $0 $832,985
Transmission $$0
Distribution Facilities $$405,082 $55,924 $461,006
Metering $$10,044 $543 $10,587
Meter Reading $$5,984 $3,740 $9,724
Billing $$41,199 $6,681 $47,880
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0 $0 $0
Total Non-Generation$462,309 $66,888 $0 $0 $529,197
Load at Customer Level MWH 16,040 6,466 0 0 22,506
Billing Demand kW 20,954 20,954
Average No. of Customers No.1,512 70 1,582
Currently Served by Schedules Residential 3ph Comm.
1ph Comm.Industrial
Area Lights
Soda 2/27/98
CITY OF SODA SPRINGSUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.36 0.38 0.00 0.00 0.37
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.36 0.38 0.00 0.00 0.37
Purchased Power Energy ¢/kWh 2.44 2.42 0.00 0.00 2.43
Generation Demand ¢/kWh 0.42 0.41 0.00 0.00 0.42
Transmission Demand ¢/kWh 0.49 0.47 0.00 0.00 0.48
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.35 3.29 0.00 0.00 3.33
Total Power Costs¢/kWh 3.71 3.67 0.00 0.00 3.70
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 2.53 0.86 0.00 0.00 2.05
Metering ¢/kWh 0.06 0.01 0.00 0.00 0.05
Meter Reading ¢/kWh 0.04 0.06 0.00 0.00 0.04
Billing ¢/kWh 0.26 0.10 0.00 0.00 0.21
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.88 1.03 0.00 0.00 2.35
Total Cost¢/kWh 6.60 4.71 0.00 0.00 6.05
Load at Customer Level MWH 16,040 6,466 0 0 22,506
Billing Demand kW 20,954 20,954
Average No. of Customers No.1,512 70 1,582
Currently Served by Schedules Residential 3ph Comm.
1ph Comm.Industrial
Area Lights
Soda 2/27/98
SOUTH SIDE ELECTRIC LINESUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 3.94 3.12 0.00 0.00 3.50
Generation Demand ¢/kWh 1.05 0.99 0.00 0.00 1.02
Transmission Demand ¢/kWh 0.83 0.78 0.00 0.00 0.80
Load Shaping ¢/kWh 0.04 0.03 0.00 0.00 0.03
Load Regulation ¢/kWh 0.03 0.03 0.00 0.00 0.03
Total Purchased Power ¢/kWh 5.88 4.95 0.00 0.00 5.39
Total Power Costs¢/kWh 5.88 4.95 0.00 0.00 5.39
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 3.07 1.53 0.00 0.00 2.26
Metering ¢/kWh 0.12 0.16 0.00 0.00 0.14
Meter Reading ¢/kWh 0.05 0.16 0.00 0.00 0.11
Billing ¢/kWh 0.04 0.02 0.00 0.00 0.03
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.87 0.46 0.00 0.00 0.65
Total Non-Generation¢/kWh 4.15 2.32 0.00 0.00 3.18
Total Cost¢/kWh 10.03 7.28 0.00 0.00 8.57
Load at Customer Level MWH 19,425 21,875 0 0 41,300
Billing Demand kW 0 66,583 66,583
Average No. of Customers No.672 247 919
Currently Served by Schedules Residential Irrigation
SSide 2/4/98
UNITY LIGHT AND POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$970,876 $916,945 $1,887,821
Generation Demand $$187,406 $127,976 $315,382
Transmission Demand $$242,131 $165,346 $407,477
Load Shaping $$1,263 $4,342 $5,605
Load Regulation $$1,105 $754 $1,859
Total Purchased Power $$1,402,781 $1,215,363 $0 $0 $2,618,144
Total Power Costs$$1,402,781 $1,215,363 $0 $0 $2,618,144
Transmission $$0
Distribution Facilities $$377,628 $280,355 $657,983
Metering $$45,786 $41,156 $86,942
Meter Reading $$5,876 $3,597 $9,473
Billing $$21,787 $15,523 $37,310
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$6,967 $9,443 $16,410
Total Non-Generation$458,044 $350,074 $0 $0 $808,118
Load at Customer Level MWH 38,931 39,243 0 0 78,174
Billing Demand kW 3,150,922 3,150,922
Average No. of Customers No.1,627 678 2,305
Currently Served by Schedules Residential Commercial
Irrigation
Unity 2/4/98
UNITY LIGHT AND POWER COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.49 2.34 0.00 0.00 2.41
Generation Demand ¢/kWh 0.48 0.33 0.00 0.00 0.40
Transmission Demand ¢/kWh 0.62 0.42 0.00 0.00 0.52
Load Shaping ¢/kWh 0.00 0.01 0.00 0.00 0.01
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.60 3.10 0.00 0.00 3.35
Total Power Costs¢/kWh 3.60 3.10 0.00 0.00 3.35
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 0.97 0.71 0.00 0.00 0.84
Metering ¢/kWh 0.12 0.10 0.00 0.00 0.11
Meter Reading ¢/kWh 0.02 0.01 0.00 0.00 0.01
Billing ¢/kWh 0.06 0.04 0.00 0.00 0.05
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.02 0.02 0.00 0.00 0.02
Total Non-Generation¢/kWh 1.18 0.89 0.00 0.00 1.03
Total Cost¢/kWh 4.78 3.99 0.00 0.00 4.38
Load at Customer Level MWH 38,931 39,243 0 0 78,174
Billing Demand kW 3,150,922 3,150,922
Average No. of Customers No.1,627 678 2,305
Currently Served by Schedules Residential Commercial
Irrigation
Unity 2/4/98
CITY OF WEISERUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$439,756 $299,799 $739,555
Generation Demand $$327,049 $215,611 $542,660
Transmission Demand $$0
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$766,805 $515,410 $0 $0 $1,282,215
Total Power Costs$$766,805 $515,410 $0 $0 $1,282,215
Transmission $$0
Distribution Facilities $$423,419 $58,289 $481,708
Metering $$13,832 $10,380 $24,212
Meter Reading $$20,711 $1,642 $22,353
Billing $$26,722 $2,043 $28,765
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$33,043 $4,459 $37,502
Total Non-Generation$517,727 $76,813 $0 $0 $594,540
Load at Customer Level MWH 27,415 18,733 0 0 46,148
Billing Demand kW 36,540 36,540
Average No. of Customers No.2,651 161 2,812
Currently Served by Schedules Residential Commercial
Small Comm.
Lighting
Weiser 2/4/98
CITY OF WEISERUNBUNDLING REPORTIDAHOGNR-E-97-1UnitSmallSecondaryPrimaryTransmissionAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 1.60 1.60 0.00 0.00 1.60
Generation Demand ¢/kWh 1.19 1.15 0.00 0.00 1.18
Transmission Demand ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 2.80 2.75 0.00 0.00 2.78
Total Power Costs¢/kWh 2.80 2.75 0.00 0.00 2.78
Transmission ¢/kWh 0.00 0.00 0.00 0.00 0.00
Distribution Facilities ¢/kWh 1.54 0.31 0.00 0.00 1.04
Metering ¢/kWh 0.05 0.06 0.00 0.00 0.05
Meter Reading ¢/kWh 0.08 0.01 0.00 0.00 0.05
Billing ¢/kWh 0.10 0.01 0.00 0.00 0.06
Uncoll. Accounts Incl. in Billing
Other Customer Services ¢/kWh 0.12 0.02 0.00 0.00 0.08
Total Non-Generation¢/kWh 1.89 0.41 0.00 0.00 1.29
Total Cost¢/kWh 4.69 3.16 0.00 0.00 4.07
Load at Customer Level MWH 27,415 18,733 0 0 46,148
Billing Demand kW 36,540 36,540
Average No. of Customers No.2,651 161 2,812
Currently Served by Schedules Residential Commercial
Small Comm.
Lighting
Weiser 2/4/98
EAST END MUTUAL ELECTRIC CO., LTD.UNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$253,884 $133,104 $386,988
Generation Demand $$61,394 $17,165 $78,559
Transmission Demand $$77,869 $21,770 $99,639
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$393,147 $172,039 $0 $0 $565,186
Total Power Costs$$393,147 $172,039 $0 $0 $565,186
Transmission $$3,712 $1,759 $5,471
Distribution Facilities (1)$$68,534 $46,739 $115,273
Metering $$730 $1,874 $2,604
Meter Reading $$1,085 $738 $1,823
Billing $$2,626 $1,021 $3,647
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$76,687 $52,131 $0 $0 $128,818
Load at Customer Level MWH 12,269 6,432 0 0 18,701
Billing Demand kW 4,085 1,142 5,227
Average No. of Customers No.410 166 576
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
EastEnd 2/4/98
EAST END MUTUAL ELECTRIC CO., LTD.UNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.07 2.07 0.00 0.00 2.07
Generation Demand ¢/kWh 0.50 0.27 0.00 0.00 0.42
Transmission Demand ¢/kWh 0.63 0.34 0.00 0.00 0.53
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.20 2.67 0.00 0.00 3.02
Total Power Costs¢/kWh 3.20 2.67 0.00 0.00 3.02
Transmission ¢/kWh 0.03 0.03 0.00 0.00 0.03
Distribution Facilities (1)¢/kWh 0.56 0.73 0.00 0.00 0.62
Metering ¢/kWh 0.01 0.03 0.00 0.00 0.01
Meter Reading ¢/kWh 0.01 0.01 0.00 0.00 0.01
Billing ¢/kWh 0.02 0.02 0.00 0.00 0.02
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 0.63 0.81 0.00 0.00 0.69
Total Cost¢/kWh 3.83 3.49 0.00 0.00 3.71
Load at Customer Level MWH 12,269 6,432 0 0 18,701
Billing Demand kW 4,085 1,142 5,227
Average No. of Customers No.410 166 576
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
EastEnd 2/4/98
FARMER'S ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$82,751 $2,693 $85,444
Generation Demand $$14,823 $474 $15,297
Transmission Demand $$20,046 $641 $20,687
Load Shaping $$0 $0 $0
Load Regulation $$0 $0 $0
Total Purchased Power $$117,620 $3,808 $0 $0 $121,428
Total Power Costs$$117,620 $3,808 $0 $0 $121,428
Transmission $$5,978 $220 $6,198
Distribution Facilities (1)$$22,269 $1,321 $23,590
Metering $$156 $53 $209
Meter Reading $$2,018 $50 $2,068
Billing $$3,960 $170 $4,130
Uncoll. Accounts Incl. in Billing $
Other Customer Services $$0
Total Non-Generation$34,381 $1,814 $0 $0 $36,195
Load at Customer Level MWH 3,841 125 0 0 3,966
Billing Demand kW 1,216 36 1,252
Average No. of Customers No.140 6 146
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
Farmers 2/4/98
CITY OF MINIDOKAUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialSt. LightingTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$17,498 $468 $17,966
Generation Demand $$4,060 $83 $4,143
Transmission Demand $$4,659 $95 $4,754
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$26,217 $646 $0 $0 $26,863
Total Power Costs$$26,217 $646 $0 $0 $26,863
Transmission $$5,234 $0 $5,234
Distribution Facilities (1)$$2,648 $291 $2,939
Metering $$276 $0 $276
Meter Reading $$837 $0 $837
Billing $$4,397 $0 $4,397
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$13,392 $291 $0 $0 $13,683
Load at Customer Level MWH 655 18 0 0 673
Billing Demand kW 229 4 233
Average No. of Customers No.55 20 75
Currently Served by Schedules Residential St. Lighting
(1) "Distribution Facilities" include "Service Entrance" costs.
Minidoka 2/4/98
CITY OF MINIDOKAUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialSt. LightingAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.67 2.60 0.00 0.00 2.67
Generation Demand ¢/kWh 0.62 0.46 0.00 0.00 0.62
Transmission Demand ¢/kWh 0.71 0.53 0.00 0.00 0.71
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 4.00 3.59 0.00 0.00 3.99
Total Power Costs¢/kWh 4.00 3.59 0.00 0.00 3.99
Transmission ¢/kWh 0.80 0.00 0.00 0.00 0.78
Distribution Facilities (1)¢/kWh 0.40 1.62 0.00 0.00 0.44
Metering ¢/kWh 0.04 0.00 0.00 0.00 0.04
Meter Reading ¢/kWh 0.13 0.00 0.00 0.00 0.12
Billing ¢/kWh 0.67 0.00 0.00 0.00 0.65
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 2.04 1.62 0.00 0.00 2.03
Total Cost¢/kWh 6.05 5.21 0.00 0.00 6.02
Load at Customer Level MWH 655 18 0 0 673
Billing Demand kW 229 4 233
Average No. of Customers No.55 20 75
Currently Served by Schedules Residential St. Lighting
(1) "Distribution Facilities" include "Service Entrance" costs.
Minidoka 2/4/98
FARMER'S ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.15 2.15 0.00 0.00 2.15
Generation Demand ¢/kWh 0.39 0.38 0.00 0.00 0.39
Transmission Demand ¢/kWh 0.52 0.51 0.00 0.00 0.52
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.06 3.05 0.00 0.00 3.06
Total Power Costs¢/kWh 3.06 3.05 0.00 0.00 3.06
Transmission ¢/kWh 0.16 0.18 0.00 0.00 0.16
Distribution Facilities (1)¢/kWh 0.58 1.06 0.00 0.00 0.59
Metering ¢/kWh 0.00 0.04 0.00 0.00 0.01
Meter Reading ¢/kWh 0.05 0.04 0.00 0.00 0.05
Billing ¢/kWh 0.10 0.14 0.00 0.00 0.10
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 0.90 1.45 0.00 0.00 0.91
Total Cost¢/kWh 3.96 4.50 0.00 0.00 3.97
Load at Customer Level MWH 3,841 125 0 0 3,966
Billing Demand kW 1,216 36 1,252
Average No. of Customers No.140 6 146
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
Farmers 2/4/98
RIVERSIDE ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationTotalGenerationDemand Related Costs $$0
Energy Related Costs $$0
Net Benefit of $$0
Secondary Sales Revenues
Demand Side Management $$0
(including Low Income DSM)
Fish Mitigation $$0
Alternative Energy Services $$0
Total Generation $$0 $0 $0 $0 $0
Purchased Power Energy $$216,179 $91,396 $307,575
Generation Demand $$49,918 $9,184 $59,102
Transmission Demand $$69,509 $12,788 $82,297
Load Shaping $$0
Load Regulation $$0
Total Purchased Power $$335,606 $113,368 $0 $0 $448,974
Total Power Costs$$335,606 $113,368 $0 $0 $448,974
Transmission $$13,820 $3,392 $17,212
Distribution Facilities (1)$$114,139 $38,822 $152,961
Metering $$781 $1,296 $2,077
Meter Reading $$4,322 $789 $5,111
Billing $$9,498 $2,603 $12,101
Uncoll. Accounts Incl. in Billing $$0
Other Customer Services $$0
Total Non-Generation$142,560 $46,902 $0 $0 $189,462
Load at Customer Level MWH 10,381 4,389 0 0 14,770
Billing Demand kW 5,610 828 6,438
Average No. of Customers No.500 137 637
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
RiverSde 2/4/98
RIVERSIDE ELECTRIC COMPANYUNBUNDLING REPORTIDAHOGNR-E-97-1UnitResidentialIrrigationAverageGenerationDemand Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Energy Related Costs ¢/kWh 0.00 0.00 0.00 0.00 0.00
Net Benefit of ¢/kWh 0.00 0.00 0.00 0.00 0.00
Secondary Sales Revenues
Demand Side Management ¢/kWh 0.00 0.00 0.00 0.00 0.00
(including Low Income DSM)
Fish Mitigation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Alternative Energy Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Generation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Purchased Power Energy ¢/kWh 2.08 2.08 0.00 0.00 2.08
Generation Demand ¢/kWh 0.48 0.21 0.00 0.00 0.40
Transmission Demand ¢/kWh 0.67 0.29 0.00 0.00 0.56
Load Shaping ¢/kWh 0.00 0.00 0.00 0.00 0.00
Load Regulation ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Purchased Power ¢/kWh 3.23 2.58 0.00 0.00 3.04
Total Power Costs¢/kWh 3.23 2.58 0.00 0.00 3.04
Transmission ¢/kWh 0.13 0.08 0.00 0.00 0.12
Distribution Facilities (1)¢/kWh 1.10 0.88 0.00 0.00 1.04
Metering ¢/kWh 0.01 0.03 0.00 0.00 0.01
Meter Reading ¢/kWh 0.04 0.02 0.00 0.00 0.03
Billing ¢/kWh 0.09 0.06 0.00 0.00 0.08
Uncoll. Accounts Incl. in Billing ¢/kWh
Other Customer Services ¢/kWh 0.00 0.00 0.00 0.00 0.00
Total Non-Generation¢/kWh 1.37 1.07 0.00 0.00 1.28
Total Cost¢/kWh 4.61 3.65 0.00 0.00 4.32
Load at Customer Level MWH 10,381 4,389 0 0 14,770
Billing Demand kW 5,610 828 6,438
Average No. of Customers No.500 137 637
Currently Served by Schedules Residential Irrigation
(1) "Distribution Facilities" include "Service Entrance" costs.
RiverSde 2/4/98