20051221IPC response 1st request IIPA.pdf

IDAHO POWER COMPANY
O. BOX 70
BOISE, IDAHO 83707
BARTON L. KLINE
Senior Attorney
An IDACORP Company
December 21 , 2005
HAND DELIVERED
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Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P. O. Box 83720
Boise, Idaho 83720-0074
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Re:Case No. IPC-05-
Idaho Power Company s Response To First Production
Requests of Idaho Irrigation Pumpers Association
Dear Ms. Jewell:
Please find enclosed for filing an original and two (2) copies of the
Company s Responses to the First Production Requests of the Idaho Irrigation Pumpers
Association regarding the above-described case.
The attachment to Response No. 23 is considered confidential by Idaho
Power and is only being furnished to those members of the Staff and intervenors that
have executed a Protective Agreement in this case. As such, it is printed on yellow
paper and marked as "Confidential" and supplied in a separate envelope.
I would appreciate it if you would return a stamped copy of this transmittal
letter to me in the enclosed self-addressed stamped envelope.
Very truly yours
Barton L. Kline
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Enclosures
Telephone [phone] Fax [phone] E-mail BK/inerwidahopower.com
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BARTON L. KLINE ISB #1526
MONICA B. MOEN ISB #5734
Idaho Power Company
O. Box 70
Boise, Idaho 83707
Telephone: [phone]
FAX Telephone: [phone]
BKlinecm.idahopower.com
MMoencm.idahopower.com
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Attorneys for Idaho Power Company
Street Address for Express Mail
1221 West Idaho Street
Boise , Idaho 83702'
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO INCREASE ITS BASE
RATES AND CHARGES FOR ELECTRIC
SERVICE IN THE STATE OF IDAHO
CASE NO. IPC-05-
IDAHO POWER COMPANY'
RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST
DATA REQUEST
COMES NOW, Idaho Power Company ("Idaho Power" or "the Company
and in response to the First Data Request of the Idaho Irrigation Pumpers Association to
Idaho Power Company dated November 23 , 2005, herewith submits the following
information:
REQUEST NO.1: Mr. Keen s testimony at page 6 indicates that six
distribution substations have been added since the beginning of 2004. Please provide
the following information regarding those distribution substations:
What is the name of each substation?
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page
What is the location of each substation? Please list county as well
as city or town that is served by the substation.
What is the capacity of each substation?
What was the cost of each substation?
RESPONSE TO REQUEST NO.and d:
Station Count /Town acit Cost
Midrose Canyon/Nampa 30 MV A $2,405 371
Valley View Canyon/Caldwell 30 MV A 635,455
Star Ada/Star 30 MV A 679 313
Ten Mile Canyon/Meridian 28 MV A 251,451
Eckert Ada/Boise 30 MV A $1 ,848 087
Lake Fork Valley/Donnelly 30 MV A 531 094
The response to this request was prepared by David L. Sikes , Planning
Manager, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO.2: Mr. Keen s testimony at page 6 indicates that
approximately 30 miles of new sub-transmission lines have been added to integrate the
six new distributions substations. Please provide a map(s) showing the location of these
new sub-transmission lines as well as the cost of these lines.
RESPONSE TO REQUEST NO.2: Maps showing the six new
substations and new sub-transmission lines to integrate them, in addition to the
Caldwell-Locust line, are attached to this response. Transmission project costs are:
Station Transmission Cost
Midrose
Valley View
Star
Ten Mile
Eckert
$586 596
$359,466
988 052
$15 591
$514 327
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 2
Lake Fork (Currently
attaching to existing
line, no costs reported
yet. )
Caldwell-Locust 797 755
The response to this request was prepared by David L. Sikes , Planning
Manager, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO.3: Mr. Keen s testimony at page 7 indicates that a
significant portion of the Company s load growth continues to occur in the Treasure
Valley area. Please answer the following:
How does the Company define the "Treasure Valley area" and in
particular the portions of the "Treasure Valley area" that is
associated with this "significant portion of the Company s load
growth"
What data does the Company have available to quantify this load
growth (rate base additions) by area (Le., by taxing district, city
boundaries, county lines, etc)?
Please provide a copy of all information that has been distributed to
the "Treasure Valley Electric Plan Community Advisory
Committee
RESPONSE TO REQUEST NO.a: Idaho Power defines the "Treasure
Valley Area" as primarily Ada and Canyon Counties. However, due to the connectivity of
the transmission system, we extend this definitional boundary to include the Ontario and
Payette areas. Growth anywhere within this area affects the transmission system.
RESPONSE TO REQUEST NO.b: Records are kept when new service
points are added by location. Attached to this response is a printout of service points
added by distribution feeder.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 3
RESPONSE TO REQUEST NO.c: All information that has been
distributed to the "Treasure Valley Electric Plan Community Advisory Committee" can
be found on Idaho Power s Web site at
http://www.idahopower.com/newsroom/proinews/tvep.htm
The response to this request was prepared by David L. Sikes, Planning
Manager, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO.4: Mr. Pengilly s testimony at page 42 provides
information regarding the impact of moving 680 non-agricultural customers from the
irrigation rate schedules to a general service rate schedule. Please provide a list of
energy and demand usage (and other appropriate data used) for each of these 680
customers that served as the basis for the results that are shown. Please provide this
information in electronic format.
RESPONSE TO PRODUCTION NO.4: The energy, demand usage and
other appropriate data are included in the Excel file "Irrigation Data Request #4.xls
included on the enclosed CD labeled First Production Request of Irrigation Pumpers -
Responses. This Excel workbook contains six worksheets: (1) Worksheet Descriptions
(2) Idaho (all accts to R7 or R9), (3) R24C to R7, (4) R24S & R25S to R7, (5) R24C to
, (6) R24S & R25S to R9.
The worksheet labeled Worksheet Descriptions contains field descriptions
for each of the other worksheets. The worksheet labeled "Idaho (all accts to R7 or R9)"
includes all the usage data for all 680 customers who would be moving to non-
agricultural rate schedules under the Company s proposal. The other worksheets
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 4
contain the same data as "Idaho (all accts to R7 or R9)" broken out into the specific rate
schedule classes and contain the component bill calculations and comparisons under
the proposed rates. All data is from calendar year 2004. For ease of analysis, the
Schedule 25 customers' bills were calculated using the proposed Schedule 24
secondary rates. All the rates used in the analysis are in the rows above the data and
final total rate impacts are below the data rows.
The response to this request was prepared by Peter Pengilly, Senior
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO.5: At page 16 of Mr. Baggs' testimony there is a
discussion regarding the data management aspects of the Phase One of the AMR
Project. If the Company has available AMR data for irrigation customers:
Please supply that data by customer on an hourly basis in
electronic format.
If the irrigation customers in the Phase One of the AMR Project are
not typical of the general irrigation class in the Idaho Power service
area , please provide an explanation regarding the differences.
RESPONSE TO REQUEST NO.a: The hourly consumption data for the
irrigation customers in the McCall and Emmett areas included in the Phase One AMR
Project is included on the CD labeled First Production Request of Irrigation Pumpers -
Responses. The data is in comma delimited text format.
It is important to note that the hourly data for ,irrigation customers is non-
billing data. Irrigation customers with AMR capability were billed based on the monthly
meter readings obtained during the normal course of the Company s cycle billing
process. Because the hourly data was not used for billing purposes , it has not been
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 5
validated. In addition, no attempt has been made to estimate usage during periods
when hourly data was not successfully retrieved. Consequently, the hourly data is the
raw" data collected from the AMR system.
RESPONSE TO REQUEST NO.5 b: The irrigation customers in the
Emmett and McCall areas are not representative of the general irrigation class
throughout the Company s service territory. Within the Emmett and McCall areas, the
total irrigation load is minimal due to the fact that the primary methods of irrigation in
both areas are flood or furrow irrigation. In addition , there are very few irrigation wells in
either area. The small number of customers that do have irrigation systems tend to
have very small systems with a typical lift of about three to ten feet from a canal or a
slough into an irrigation ditch.
The response to this request was prepared by James L. Baggs, General
Manager, Strategic Initiatives and Compliance, Idaho Power Company, in consultation
with Barton L. Kline, Senior Attorney, Idaho Power Company.
REQUEST NO.6: Please provide a copy of all model runs and other
support data that was used to prepare the Company s exhibits in electronic format. If
certain procedures are required to run things like the Company s class cost of service
study, please provide a copy of those procedures as well.
RESPONSE TO REQUEST NO.6: All exhibits and workpapers available
in electronic format are included on the CD labeled First Production Request of
Irrigation Pumpers - Responses. The Company s class cost-of-service study is in Excel
format and no special procedures are needed to use the model.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 6
The response to this request was prepared by Maggie Brilz , Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
REQUEST NO.7: Please provide a copy of all input data to Exhibits 20
and 21 in both hard copy and electronic format.
RESPONSE TO REQUEST NO.7: The information displayed on
Exhibit 20 is the input to the exhibit. The data presented on the exhibit was produced
from a run of the Aurora model , which is a comprehensive electric market price
forecasting model that simulates the entire region. Idaho Power Company is prevented
by its license with EPIS from furnishing the Aurora input databases to those who are not
licensed users of Aurora. We can , however, provide Idaho Power Company input data
that was used in the simulations. A printout of this data was provided in Response No.
5 to the First Production Request of the Industrial Customers of Idaho Power Company.
The data in electronic format is included on the enclosed CD labeled First Production
Request of Irrigation Pumpers - Responses.
The information contained in Exhibit 21 includes all inputs to the
regression shown. Approved PCA methodology uses a natural logarithm of April
through July Brownlee runoff (labeled "runoff') to predict annual net power supply
expenses (labeled "predicted y
).
Modeled April through March net power supply
expenses (labeled lInpsc ) derived from Exhibit 20 along with the natural logarithm of the
April through July Brownlee runoff are the inputs to the regression.
To ensure compliance with FERC's Standards of Conduct, the
transmission inputs , in addition to being provided in the response to this production
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 7
request, are posted on the Idaho Power Company OASIS in the folder entitled 2005
Idaho Retail Rate Case Documents.
The response to this request was prepared by Gregory W. Said , Manager
Revenue Requirement, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
REQUEST NO.8: For each month since January 2003, please supply the
monthly usage of Schedule 24 and 25 customers in the Idaho Jurisdiction and the
system as a whole.
RESPONSE TO REQUEST NO.8: The requested information is
enclosed with this response.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
REQUEST NO.9: With respect to the Company s Load Research data
please provide for each sample customer with valid data that was sampled between
January 2003 and the most recent month available the following:
Customer identification number;
Customer rate schedule;
Strata to which it belongs;
Raw hourly usage data;
Raw hourly usage data modified to reflect losses;
On an hourly basis, any additional calibrations that are applied to
the Load Research data before it is applied to develop the
allocation factors used in the Company s cost of service study in
this case.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 8
Please provide copies of the formulas (and data) used to expand
the Load Research data up to the population as a whole as used in
the class cost of service study in this case.
RESPONSE TO REQUEST NO.9: In response to items 9., 9., 9., and
, the customer identification numbers, rate schedule, stratum , and hourly usage data
are included on the CD labeled First Production Request of Irrigation Pumpers -
Responses in the Excel workbooks with "hourly" in the file name. Note that the hours
on these spreadsheets are labeled with hour starting, not ending, times.
Raw hourly usage data modified to reflect losses (9.e) does not exist.
However, the hourly usage data coincident with the system peaks or the group peaks
may be adjusted to reflect losses using the system loss coefficients contained in the
response to 9.
In response to item 9.f, the Company did not calibrate the hourly Load
Research data provided in response to 9., and the only Load Research data applied to
develop the allocation factors used in the Company s cost of service study in this case
are the sample mean hourly usage at the hour of the month system peak (system-
coincident demand per customer), the sample mean hourly usage at the hour of the
monthly group peak (group-coincident demand per customer, which may be non-
coincident with the system peak), and the sample mean average demand (monthly
energy per customer divided by hours in the month).
The Company s allocation factors do not rely on the assumption that these
sample means (system-coincident, group-coincident, and average demand) represent
the population means , but only on the assumption that the ratios of the sample means
represent the ratios of the population means. The ratios were applied to the average
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 9
demands obtained from calendar-month usage estimated from monthly billing data. No
additional calibrations were applied to the ratios.
In response to item 9.g, the formulas (and data) used to expand the Load
Research data up to the population as a whole as used in the class cost of service
study in this case are contained in the Workspace spreadsheets in the
D&EMaster04rc.xls and D&EMaster05rc.xls Excel workbook on the CD. The other
spreadsheets in the workbooks contain the input data used in the calculations in the
Workspace spreadsheet. Additional documentation can be found in the LodeMethod
Word document and the Stratum Weights spreadsheet.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
REQUEST NO.1 0: Please provide for each month from January 2003
forward a copy of the monthly checks that the Company makes regarding how well the
Load Research sample data reflects the actual population usage.
RESPONSE TO REQUEST NO. 10: The relative precision of the ratio
estimates of the sample means is contained in the monthly Load Research summary
reports provided in response to Request No. 12.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 10
REQUEST NO. 11: Please provide for each month from January 2003
forward a listing of the calendar month usage for the Schedule 24 and Schedule 25 in
the Idaho Jurisdiction.
RESPONSE TO REQUEST NO. 11: The requested information is
provided with this response.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO. 12: Please provide a copy of any monthly Load Research
summary reports that have been produced between January 2003 and the present.
RESPONSE TO REQUEST NO. 12: The monthly Load Research
summary reports are included on the CD labeled First Production Request of Irrigation
Pumpers - Responses in the report files with "summary" in the file name. In addition
the monthly coincident demands have been summarized in the annual "Demand &
Energy" workbooks.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
REQUEST NO. 13: Please provide a copy of the bill frequency
distribution for each month of the test year for Schedules 1 , 9, 19, 24 , and 25.
RESPONSE TO REQUEST NO. 13: The Company does not routinely
prepare bill frequency reports. Therefore, no reports are available for the test year.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 11
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
REQUEST NO. 14: Please provide in electronic format, on an hourly
basis , for the period January 1 , 2003 through the most recent month available the
following data:
Total system input;
System input from Company owned generation (stating hydro, coal
and other generation separately);
System input from firm purchases , stating each purchase
separately by source and type of purchase (LF , IF, SF);
The cost of each firm purchase listed in "C" above;
System input from non-firm and/or economy purchases , stating
each purchase separately;
The cost of each non-firm and/or economy purchase listed in "
above;
System input from exchanges into the system , stating each
exchange separately;
System input from Unit purchases;
Other system inputs , stating for each "other" input the type and the
source of the input;
System losses;
Requirements Wholesale sales (RQ);
Long-term firm Wholesale sales (LF), stating each one separately;
Intermediate-term firm Wholesale sales (IF), stating each one
separately;
Short-term firm Wholesale sales (SF), stating each one separately;
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 12
Unit sales, Wholesale (LU) or otherwise, stated separately;
Non-firm and/or economy Wholesale sales (OS), stated separately;
The revenue collected for each hour of each non-firm and/or
economy purchase listed in "P" above;
Exchanges out of the system, stating each exchange separately;
Other system outputs, stating for each "other" output the type and
the recipient of the output;
Inadvertent power flows into or out of the system;
The power available (at input level) to supply retail load once
Wholesale , Exchange , Wheeling, and Inadvertent has been
subtracted;
Losses assigned to each retail jurisdiction;
Losses assigned to wholesale sales;
Total firm retail (non-special contract) load by jurisdiction (assuming
that this data is not directly metered on an hourly basis, please
indicate which data in this response can be added or subtracted
each hour to derive this information);
In the aggregate, the total firm special contract customer load by
jurisdiction (If need be, use identification codes to specific individual
special contract customer loads.
RESPONSE TO REQUEST NOS. 14 a THROUGH 14
j:
The requested
data is included on the enclosed CD labeled "First Production Request of Irrigation
Pumpers - Responses . A separate file is included for each year, 2003 , 2004 , and
2005.
To use these files , utilize the drop-down menus found on line 6. For
instance , clicking on the arrow on line 6 of column A will show the drop-down menu for
system load data. To view the system load data, select "system load" from the menu.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 13
This selection will bring up the system load data starting in column AS. The specific
responses are identified by the column headings on line 5.
The response to this request was prepared by David Bean , Controller
Power Supply, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 14 k: The requested data for
Requirements Wholesale sales (RQ) is included on the enclosed CD labeled "First
Production Request of Irrigation Pumpers - Responses . The hours listed are standard
time and are not adjusted for Daylight Savings Time.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NOS. 14 I THROUGH 14 u: The requested
data is included on the enclosed CD labeled "First Production Request of Irrigation
Pumpers - Responses . A separate file is included for each year, 2003 , 2004, and
2005.
To use these files, utilize the drop-down menus found on line 6. For
instance, clicking on the arrow on line 6 of column A will show the drop-down menu for
system load data. To view the system load data, select "system load" from the menu.
This selection will bring up the system load data starting in column AS. The specific
responses are identified by the column headings on line 5.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 14
The response to this request was prepared by David Bean , Controller
Power Supply, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 14 v: Loss factors for peak demand and
energy by voltage for each jurisdiction including FERC wholesale customers are
included on the enclosed CD labeled "First Production Request of Irrigation Pumpers -
Responses" in the "Demand & Energy" workbooks provided as part of the Response to
Request No. 12. These are system loss factors by voltage level and are not calculated
on an hourly basis.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 14 w: Please refer to the response to
Request No. 14 v.
The response to this reque~t was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 14 x: The monthly energy and
coincident demand information is provided as part of the Response to Request No 9.
Information is not available by hour.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline,
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 15
RESPONSE TO REQUEST NO. 14 y: INL, Micron , and Simplot monthly
energy and coincident demand information is provided as part of the Response to
Request No.9. In the past some special contract customers have indicated that they
consider energy and demand information on an hourly basis competitively sensitive
information. As a result, hourly information is not included as part of this response.
the three identified special contract customers do not object to the release of this hourly
information, Idaho Power Company can provide it. Otherwise , the requested hourly
information may only be viewed at the Company s corporate headquarters by those
persons that have signed a Protective Agreement.
The response to this request was prepared by Paul Werner, Load
Research Team Leader, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
REQUEST NO. 15: For each firm wholesale sale that took place in 2003
(through the most recent month available) please list for each month:
The name of the entity sold to;
The type (FERC classification) of the contract;
The pricing mechanism (fixed , rate schedule, market index
formula, etc.
The amount of energy sold;
The dollars paid for demand charges;
The dollars paid for energy charges; and
The total dollars paid.
RESPONSE TO REQUEST NO. 15: The responses to this request are
included in the files provided in Response to Request No. 14.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 16
The response to this request was prepared by David Bean , Controller
Power Supply, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
REQUEST NO. 16: For each firm wholesale purchase that took place in
2003 (through the most recent month available) please list for each month:
The name of the entity purchased from;
The type (FERC classification) of the contract;
The pricing mechanism (fixed, rate schedule , market index
formula, etc.
The amount of energy purchased;
The dollars paid for demand charges;
The dollars paid for energy charges; and
The total dollars paid.
RESPONSE TO REQUEST NO. 16: The responses to this request are
included in the files provided in Response to Request No. 14.
The response to this request was prepared by David Bean , Controller
Power Supply, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
REQUEST NO. 17: Please provide a copy of each Marginal Cost Study
that has been presented to the Commission or the Commission Staff for each year
since 2002.
RESPONSE TO REQUEST NO. 17: Idaho Power has not prepared nor
has it presented to the Commission or the Commission Staff any Marginal Cost Studies
since 2002. The Company did , however, perform an analysis of the generation and
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 17
transmission marginal costs in 2003 and 2005. A copy of the 2003 analysis has been
provided with the Company s Response to Request No.2 of the First Production
Request of the ICIP to Idaho Power. The 2005 analysis can be found in Ms. Brilz
workpapers, pages 58-65.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company.
REQUEST NO. 18: With respect to the marginal demand costs used in
Exhibit 46 , what is the exact source of these numbers (historic/current contract values
projections, current values of indexed prices, etc.
RESPONSE TO REQUEST NO. 18: The marginal demand costs used in
Exhibit 46 are described on pages 59 and 60 of Ms. Brilz s workpapers.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company.
REQUEST NO. 19: With respect to the marginal energy costs used in
Exhibit 46 , what is the exact source of these numbers (historic/current contract values
projections, current values of indexed prices , etc.)? Are these prices for firm energy?
RESPONSE TO REQUEST NO. 19: The marginal energy costs used in
Exhibit 46 are described on pages 58 and 59 of Ms. Brilz s workpapers.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 18
REQUEST NO. 20: With respect to the demand values listed on
Exhibit 46, what was the date and time that each peak occurred?
RESPONSE TO REQUEST NO. 20: The demand values listed on
Exhibit 46 are the "normalized" coincident peak demands determined through the
surrogate demand normalization methodology agreed to by the parties as part of the
cost-of-service workshop process. These demand values were determined through the
use of the five-year median demand ratios from the load research samples applied to
the normalized monthly energy values for each customer class. The median demand
ratios did not all occur in the same year. The year, day, and hour of the monthly system
coincident demands used to compute the median demand ratios varied from class to
class and from month to month. Consequently, each set of monthly "normalized"
coincident peak demands in Exhibit 46 was not based on or associated with any specific
date and time.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
REQUEST NO. 21: For each of the last five years, what was the date and
time of the monthly system peak?
RESPONSE TO REQUEST NO. 21: The requested information is
enclosed with this response.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 19
REQUEST NO. 22: During the hour of the monthly peak for each of the
last five years, please provide the following:
How many megawatts of generation were out of service for planned
maintenance?
How much electricity was generated from Company owned hydro?
How much electricity was purchased from Company owned thermal
power?
How much electricity was purchased from QF suppliers?
How much electricity was brought in through exchanges?
How much (non-QR) electricity was purchased and at what price?
Please list each transaction separately, stating name of seller
MWH purchased, purchase price, and type of purchase (LF , RQ,
, OS, etc.
How much electricity was sold off-system and at what price?
Please list each transaction separately, stating name of purchaser
MWH sold , sale price, and type of sale (LF , RQ, SF , OS , etc.
RESPONSE TO REQUEST NO. 22: The requested material is included
on the enclosed CD labeled First Production Request of Irrigation Pumpers-
Responses.
The response to this request was prepared by David Bean , Controller
Power Supply, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
REQUEST NO. 23: For each of the next three years , what are the dates
of scheduled maintenance , name of the units being maintained , and the megawatts
being taken out of service?
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 20
RESPONSE TO REQUEST NO. 23:
Power Production Maintenance Scheduling. Maintenance scheduling
for Idaho Power s generating units is a dynamic process. It is driven by factors that can
change from year to year, month to month , or even week to week.
Elements that are considered when putting together an annual
maintenance schedule include: snow pack, stream flow and reservoir conditions
predicted system loads (peak periods and off peak periods), transmission constraints or
requirements, planned transmission and substation construction projects, available work
force, contractor requirements, failures or other problems associated with equipment
occasional non-routine maintenance to units and/or associated equipment, equipment
upgrade opportunities, and forward price indications.
Maintenance is always subject to cancellation or change due to real time
operational conditions.
Specific Dates. Idaho Power considers the specific dates for scheduled
outages for its generating units to be valuable competitive information. As a result , the
enclosed information on specific scheduled outages is only being supplied to those
members of the Staff and intervenors that have executed the Protective Agreement.
Enclosed is the 2006 maintenance schedule for hydro and thermal generation units.
Also enclosed is the 2007 and 2008 schedule for coal-fired units. Non-coal-fired unit
maintenance is not scheduled beyond one year due to the wide variability of water
conditions , unit operating hours , and crew availability.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 21
The response to this request was prepared by Darwin D. Pugmire
Manager, Power Production , Idaho Power Company, in consultation with Barton L.
Kline , Senior Attorney, Idaho Power Company.
REQUEST NO. 24: With respect to the system , as well as class
demands and energies listed on Exhibit 46 , if the values listed are not actual (or directly
derived from load research data for that exact hour), please provide a description as
well as all data used to derive the values listed in Exhibit 46.
RESPONSE TO REQUEST NO. 24: The derivation of the demands listed
on Exhibit 46 is provided in the response to Request No. 20. The data used to derive
the demands is included in the file named Demand&EnergyNorm05rc.xls provided in
the Response to Request No. 12. The energy values listed on Exhibit 46 are the
normalized calendar month energy usages adjusted for losses. A description of the
process used to derive the normalized values for 2005 is included with this response.
The data used to derive the energy values is included in Ms. Schwendiman
workpapers, pages 142 - 144.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
REQUEST NO. 25: Please provide the hourly load data for each of the
Company s distribution substations from January 1 , 2002 though the most recent month
available.
RESPONSE TO REQUEST NO. 25: Response and objection filed with
Commission on December 16 , 2005.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 22
REQUEST NO. 26: How many miles of primary and secondary conductor
are found in the Idaho Jurisdiction? Please describe how this figure is derived.
RESPONSE TO REQUEST NO. 26: The facility records are maintained in
a Geographic Information System (GIS) database. The data structure within the GIS
and the calculations used to determine the line mileage for reporting was changed after
2002. The underground poly-phase secondary wires were previously reported counting
each of the multi-phases as a separate wire. The current practice is to count each
section of underground secondary line as a single asset or wire, because the property
unit is issued in linear feet for the pre-assembled secondary material in the work orders.
Thus the underground secondary wire miles will be almost a factor of three lower than
values reported using the information and methodology for 2002 and earlier.
The GIS system maintains a length value derived from the shape of the
line. Line Lengths were then multiplied by the following factors based on the number of
wires:
Single Phase OH Primary Lines w/Neutral wire x 2.
Two Phase OH Primary Lines w/Neutral wire x 3.
Three Phase OH Primary Lines w/Neutral wire x 4.
Single Phase OH Primary Lines wo/Neutral wire x 1.
Two Phase OH Primary Lines wo/Neutral wire x 2.
Three Phase OH Primary Lines wo/Neutral wire x 3.
Single Phase UG Primary Lines w/Concentric Neutral wire x 1.
Two Phase UG Primary Lines w/Concentric Neutral wire x 2.
Three Phase UG Primary Lines w/Concentric Neutral wire x 3.
As of April 2005 the primary conductor wire miles total 53 726 and the secondary
conductor wire miles total 3,469.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 23
The response to this request was prepared by David L. Sikes, Planning
Manager, Idaho Power Company, in consultation with Barton L. Kline , Senior Attorney,
Idaho Power Company.
REQUEST NO. 27: On page 13 of Brilz workpapers there are various
values listed for distribution accounts. Please answer the following:
Please describe the methodology of dividing these accounts into
primary and secondary components. Please give examples.
Please provide a general explanation regarding what is meant by
the primary component verse the secondary component.
Can the direct assignments listed be traced to specific rate
schedules in the Company s cost of service study?
RESPONSE TO REQUEST NO. 27 a: Property units in distribution
accounts are designated as primary or secondary based on the purpose for which they
are used (see the response to Request No. 27b). The identification occurs at the time
of installation and is based on the information included on the actual work orders
prepared as part of the Company s facilities installation process.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 27 b: Distribution equipment is classified
as either primary or secondary based on its usage. Distribution equipment located
between substations and the transformers that ultimately serve customers is considered
primary. Distribution equipment used to directly provide service to customers is
considered secondary.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 24
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 27 c: The direct assignments listed by
rate schedule on page 13 of Ms. Brilz s workpapers can be found on Exhibit No. 35
page 7, column N , lines 83-86. On Exhibit No. 35, these direct assignment amounts are
functionalized as Secondary Lines - Direct. The total Electric Plant in Service
functionalized to Secondary Lines - Direct, $14 858 161 , can be found on Exhibit No.
, page 12 , column N , line 110. This amount includes the portion of General Plant
allocated to the Secondary Lines - Direct function. The total Electric Plant in Service
amount of $14 858 161 functionalized to Secondary Lines - Direct can be found on
Exhibit No. 37, Allocation to Classes , on page 3 , column A, line 77. This amount is
allocated to the various customer classes using the DA3647 allocation factor. The
array of values comprising the DA3647 allocator can be found on Exhibit No. 37 , pages
43 and 44, line 27. This array matches the values of the direct assignments listed on
workpaper page 13.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company.
REQUEST NO. 28: On page 16 of Brilz workpapers there are various
values listed for Account 369. Please answer the following:
How were the figures of $219.33 and $307.37 for the average cost
of single-phase and three-phase customers derived? Please supply
supporting study.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 25
What do the figures of $219.33 and $307.37 for the average cost of
single-phase and three-phase customers represent as far as the
average length of a Service?
What is the average length of a Service for an Irrigation customer?
RESPONSE TO REQUEST NO. 28 a: The Company s PassPort work
management system , which is used to provide work order estimates for new line
construction , was used to derive the costs of both 60-foot and 70-foot single-phase and
three-phase service drops. The single-phase cost of $219.33 was derived by utilizing
PassPort to compute the cost of a 70-foot service drop using #2 conductor and the
necessary conductor hardware , requiring one hour of lineman labor, and requiring one
hour s usage of a linebed or bucket truck. The three-phase cost of $307.37 was
derived utilizing PassPort to compute the cost of a 70-foot service drop using #2
conductor with one extra strand of conductor and the necessary conductor hardware
requiring one hour of lineman labor, and requiring one hour s usage of a linebed or
bucket truck. The results from the PassPort computation are shown on page 18 of Ms.
Brilz s workpapers.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
RESPONSE TO REQUEST NO. 28 b: The figures of $219.33 and
$307.37 represent the estimated costs of a 70-foot single-phase and a 70-foot three-
phase service drop as generated by the Company s PassPort work management
system.
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 26
The response to this request was prepared by Maggie Brilz , Director of
Pricing, Pricing and Regulatory Services, Idaho Power Company, in consultation with
Barton L. Kline , Senior Attorney, Idaho Power Company:
RESPONSE TO REQUEST NO. 28 c: The Company does not maintain
detailed data on the length of the service drop for each customer and therefore cannot
calculate the actual average service drop length by customer class. However, based on
the expertise of the Company s agricultural representatives and their knowledge of the
Company s customers , it is believed that no service drop for irrigation customers
exceeds 120 feet or is less than 10 feet and on average is approximately 60 feet in
length.
The response to this request was prepared by Maggie Brilz, Director of
Pricing, Pricing and Regulatory Services , Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
DATED at Boise, Idaho , this 21st day of December, 2005.
0Ji~BARTON L. KLINE
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S RESPONSE TO IDAHO IRRIGATION
PUMPERS ASSOCIATION'S FIRST DATA REQUEST Page 27
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FIRST PRODUCTION REQUEST
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PUMPERS ASSOCIATION , INC.
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REQUEST NO.
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CASE NO. IPC-O5-
FIRST PRODUCTION REQUEST
OF THE IDAHO IRRIGATION
PUMPERS ASSOCIATION, INC.
ATTACHMENT TO
RESPONSE TO
REQUEST NO.
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
3993
0 101 360 5432313
0107 232 2844289
0 107B 6781
0 109P 12810007
01095 23897751
0 115 19153.
0 119P 10644979
0 124CB 20005
0 124SB 494823
0140 2392
0 142M 6373
0166
0001 323898
0007 183155
0 0095 1068413
0 009SB 163080
0015 6758.
AIKN11
AIKN11 101 291682
AIKN11 107 2150
AIKN12
AIKN12 101 328271
AIKN12 107 1290
AIKN12 124SB 201509
AIKN13
AIKN13 107 39520
AIKN13 1095 1626600
ALMA 11
ALMA 11 101 48799
ALMA 11 107 21291
ALMA 12
ALMA 12 101 1342
ALMA 12 107 135133
ALMA 13
ALMA 13 101 87698
ALMA 13 107 65864
ALMA 13 1095 311272
ALMA14
ALMA14 101 18620
ALMA14 107 61184
ALMA14 1095 952268
ALMA 15
ALMA 15 101 19408
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
ALMA16
ALMA16 101 2372
ALMA 16 107 25959
ALMA 17
ALMA 17 101 68183
ALMA 17 107 15682
ALMA 17 109S 184080
ALMA 18
ALMA 18 107 91645
ALMA 18 109S 33376
ALMA 18 115 3288
ALMA 18 142M 11811
AMDM11
AMDM11 101 11170
AMDM11 107 37230
ARTN11
ARTN 13
ARTN 13 101 30623
ARTN13 107 7383
ARTN13 124SB 16886
BCRT11
BCRT11 101 53616
BCRT11 \07 34920
BCRT11 109S 417158
BCRT12 107 15764
BCRT12 109S 27401
BKA T11 124
BKA T11 101 198332
BKA T11 107 21243
BKA T11 109S 113120
BKAT12
BKAT12 101 33315
BKAT12 109S 265920
BKAT13
BKAT13 101 382282
BKAT13 107 895
BKAT13 124SB 18205
BKAT14 116
BKAT14 101 1048912
BKAT14 107 11892
BKCK11
BKCK11 101 15216
BKCK12 101 67043
BKCK12 107 21989
BKFT11
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
BKFT11 101 13944
BKFT12
BKFT12 101 88113
BKFT12 107 241032
BKFT12 109S 6234842
BKFT13
BKFT13 101 153768
BKFT13 107 6252
BKFT13 109S 5853
BKFT14
BKFT14 107 15251
BKFT15
BKFT15 107 159887
BKFT15 109S 1078034
BKFT16
BKFT16 101 33823
BKFT16 109S 612760
BKFT16 124SB 70961
BKFT16 142M 25721
BKFT17
BKFT17 101 438878
BKFT17 107 16932
BKFT17 124SB
BKHN41
BKHN41 101 18429
BKHN41 107 13452
BKHN42 109S 303640
BLDR32
BLDR32 101 892669
BLDR32 107 40276
BLDR32 109S 6442
BLDR41
BLDR41 101 212814
BLDR41 107 7923
BLDR41 109S 16800
BOBN41
BOBN41 101 225648
BOBN41 107 7472
BOBN41 109S 4016
BOBN42 163
BOBN42 101 133 1865572
BOBN42 107 86654
BOBN43
BOBN43 101 27742
BOBN43 107 47397
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
BOBN43 109S 357883
BOBN44
BOBN44 101 31191
BOBN44 107 13434
BOBN44 109S 135760
BOBN45
BOBN45 101 147847
BOBN45 107 59993
BOBN45 109S 211646
BOBN45 142M 1499
BOIS11
BOlS11 101 9057
BOIS12
BOIS12 101 24478
BOIS12 107 10294
BOIS14 107 12077
BOIS17
BOIS17 101 11966
BOIS17 107 6714
BOIS19
BOIS19 101 24807
BOIS19 107 2949
BOIS19 109S 320400
BOIS19 115 3151
BOIS20
BOIS20 107 12426
BOIS20 109S 50192
BOIS21 109S 176980
BOIS22
BOIS22 101 43274
BOIS22 107 8119
BOIS22 109S 1519160
BOIS23
BOIS23 107 10147
BOlS23 109S 1104013
BOMT41
BOMT41 101 811894
BOMT41 107 47528
BOMT41 124SB 62570
BOMT42
BOMT42 101 820809
BOMT 42 107 120441
BOMT 42 109P 2531226
BOMT 42 109S 1483691
BOMT42 124SB 110144
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
BOMT 42 007 36608
BRDR12
BTLR 11
BTLR 11 101 93122
BTLR 11 107 10753
BTLR 12
BTLR12 101 145382
BTLR12 107 15290
BTLR12 109S 320120
BTLR13
BTLR13 101 160926
BTLR13 107 29967
BTLR 13 109S 51530
BTLR14
BTLR14 101 179113
BTLR15
BTLR15 101 61338
BTLR15 107 63835
BTLR 15 109S 31323
BTLR16
BTLR16 101 67919
BUBG41
BUBG41 101 19510
BUBG41 124SB 418640
BUBG42
BUBG42 101 40789
BUBG42 124SB 69734
BUBG43
BUBG43 101 15247
BUBG43 107 1033
BUBG44
BUBG44 101 292258
BUBG44 109S 1373306
BUBG44 124SB 2755
BUGU41
BUGU41 101 1264
BUGU41 107 32540
BUGU41 109S 1221600
BUGU41 109SB 214480
BUGU41 115 3128
BUGU41 124S 147786
BUGU41 124SB 11672
BUGU41 184CS 155890
BUGU42
BUGU42 101 65329
5ervice Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
BUGU42 1245B
BUHL 11
BUHL 11
BUHL 11
BUHL 11
BUHL 12
BUHL 12 101
BUHL 12 107
BUHL 12 1245B
BUHL 13
BUHL 13 101
BUHL 13 107
BUHL 14
BUHL 14 101
BUHL 14 107
BUHL 14 1245B
CACK41
CACK41 101
CACK41 1245B
CACK42 107
CACK42 1245B
CACK43
CACK43 101
CACK43 107
CACK43 1095
CACK43 1245B
CAR011
CAR011
CAR011
CAR011
CAR011
CAR011
CAR012
CAR012 101
CAR012 107
CAR012 1095
CAR012 115
CAR013
CAR013 001
CAR013 007
CAR013 0095
CATR12
CATR12 1245
CATR12 1245B
COAL 11
101
107
1245B
101
1245B
001
007
0245B
New 5ervice kWh
35272526 20 247839
20221
142454
54017
2810
8513912 14 209107
26843
104473
7224
117670
40079
6377
9234
3401
40208
182
42052
134122
50078
20498
54455
11105
10847622 40 462947
19574
707103
2 4658.
15851
117078
192949
8760
9508074
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
COAL 11 101 760551
COAL 11 107 86776
COAL 11 109P 4544560
COAL 11 109S 975378
COAL 11 142M 2470
COAL 11 166
COAL 12
COAL 12 101 38264
COAL 12 107 36144
COAL 12 109S 393640
COAL 13
COAL 13 107 98283
COAL 13 109S 20200
COAL 14 107 107534
COAL 14 109S 1481040
COAL 14 166
COAL 15
COAL 15 101 52240
COAL 15 107 48371
COAL 16
COAL 16 101 497888
COAL 16 107 43738
COAL 16 109S 3123239
COAL 16 142M 4556
COAL 17
COAL 18 107
COAL 18 101 138 1800793
COAL 18 107 52153
COAL 18 109S 50440
COWL 11
COWL11 101 172452
COWL12
COWL12 107 23947
COWL 13
COWL 13 101 1181740
COWL 13 107 27239
COWL 13 109S 76665
COWL 13 124CB 448
COWL13 124SB 109444
COWL 14
COWL14 101 167131
COWL14 109S 4197
COWL 15
COWL 15 101 211226
COWL 15 107 23514
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
COWL 15 1095
COWL 16
COWL 16 101
COWL16 107
COWL 16 124SB
COWL 17
COWL 17 101
COWL 17 107
COWL 17 1095
CHUT11
CHUT11
CHUT11
CHUT11
CHUT12
CHUT12 101
CHUT12 107
CHUT13
CHUT13 101
CHUT13 107
CHUT14
CHUT14 101
CHUT14 107
CHUT14 1095
CHUT15
CHUT15 101
CHUT15 107
CHUT15 1095
CHUT16
CHUT16 101
CHUT16 107
CHUT16 1095
CHUT17
CHUT17 101
CHUT18
CHUT18 101
CHUT18 107
CHUT18 1095
CMBG11
CMBG11 101
CMBG11 124SB
CMBG12
CMBG12 101
CMBG12 001
CNCK11
CNCK11 101
101
107
109SB
New Service kWh
25644155 32 651447
23620
16123811 24 434033
79523
16322865 89 1188404
32687
7937012
11863
6891263 159 1477836
1712660 141 146158211 158873
53690512 31 200343
11241
197630
52280
4453
1808034 159 100896144
111083
17115
160450
43888
201519 11 226195
5223310 19 564373
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
CNCK11 107 15651
CNCK11 124S8 110053
CNCK12
CNCK12 101 317564
CNCK12 107 89114
CNCK12 109S 121838
CNCL 11
CNCL 11 101 127864
CNCL 11 107 6009
CNCL 12
CNCL 12 101 57940
CNCL 12 107 40046
COVR 12
COVR 12 101 7152
COVR 12 124S8 380643
CSCD11
CSCD11 101 195599
CSCD11 107 12537
CSCD11 109S 119600
CSCD12
CSCD12 101 149368
CSCD12 107 20012
CSCD13
CSCD13 101 660418
CSCD13 107 78804
CSCD13 109S 43990
CSCD13 124S 27744
CWJY12
CWJY12 001 12922
CWJY12 024S8 13119
DALE41
DALE41 100 14824
DALE41 101 55338
DALE41 107 52859
DALE41 109S 268561
DALE41 124S8 157153
DALE42
DALE42 101 28324
DALE42 124S8 272123
DALE43
DALE43 101 38551
DALE43 107 2530
DALE44
DALE44 101 96767
DALE44 107 6767
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
DALE44 124S8 705397
DESN13 101 1670
DESN13 124S 24711
DESN13 124S8 25769
DIXI31
DIXI31 101 112269
DIXI31 107 2136
DIXI31 124S8 25582
DRKE11
DTRC11
DTRC11 101 86310
DTRC11 124S8 13762
DTRC12 109S 136650
DUFN41
DUFN41 101 4122
DUFN41 107 659
DUFN41 124S8 441048
DUFN42
DUFN42 124S8 297755
DUFN43
DUFN43 107 2783
DUFN43 109S 165200
DUFN44
DUFN44 124S8 382757
DWSY11
DWSY11 001 9631
EAGL 12 143
EAGL 12 101 579291
EAGL 12 107 212753
EAGL 12 109S 63616
EAGL 13
EAGL 13 101 647517
EAGL 13 109S 305684
EAGL 14
EAGL 14 101 1141939
EAGL 15
EAGL 15 101 487155
EAGL 16
EAGL 16 101 1743366
EAGL 16 124S 139011
EDEN41
EDEN41 101 45320
EDEN41 107 33417
EDEN41 109S8 32191
EDEN41 124S8 41664
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
EDEN42
EDEN42 101 377590
EDEN42 \07 6870
EDEN42 \24S8 158298
EDEN43
EDEN43 101 101408
EDEN43 107 1634
EDEN43 124S8 139358
EKHN11
EKHN11 101 543700
EKHN11 109S 2532400
EKHN12
EKHN12 101 263477
EKHN12 107 21760
EKHN12 109S 152240
ELMR41 252
ELMR41 101 132 1583216
ELMR41 107 63656
ELMR41 109S 298760
ELMR41 115 1365.
ELMR42
ELMR42 101 103745
ELMR42 107 13932
ELMR42 115 510
EMET11
EMET11 101 124230
EMET11 107 32169
EMET11 109S 77315
EMET12
EMET12 101 77471
EMET12 107 80239
EMET12 109S 190667
EMET12 115 782
EMET13
EMET13 101 1091236
EMET13 107 157364
EMET13 124S8 13925
EMET14 100
EMET14 101 1240980
EMET14 107 527585
EMET14 109S 728647
ETGT12 159
ETGT12 101 114 1512531
ETGT12 107 141265
ETGT12 109S 3991
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
ETGT12 124S8 81504
ETGT13
ETGT13 101 28986
ETGT13 107 2108
ETGT14
ETGT14 101 99127
ETGT14 107 50798
ETGT15 199
ETGT15 101 132 1287101
ETGT15 107 18570
ETGT15 109S 16000
ETGT16
ETGT16 101 252889
ETGT16 107 59026
ETGT16 109S 28800
ETGT17
ETGT17 101 169144
ETGT17 107 15156
ETGT17 124S8 294412
FALS11
FALS11 101 88359
FALS11 107 29564
FALS12
FALS12 101 118
FALS12 107 5293
FALS13
FALS13 101 59821
FALS13 107 14772
FALS14 124S8 587
FALS15
FALS15 101 18575
FALS15 107 3776
FATP11
FATP11 101 26532
FATP11 109S 808960
FATP11 124S8 32086
FATP12
FILR11
FILR11 101 14207
FILR11 107 17531
FILR12
FILR12 101 373450
FILR12 109S 102160
FILR12 124S8 49004
FILR13
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
FILR13 101 460185
FILR13 107 14478
FILR13 124SB 65902
FSGL41 101 6674
FSGL41 107 823
FSGL41 107B 6780
FSGL41 124CB
FSGL41 124SB 1761
FTHL 11
FTHL 11 101 37173
FTHL 11 124SB 1062
FTHL 12
FTHL 12 101 22695
FTHL 12 107 279
GARY11
GARY11 101 28256
GARY12 101 53270
GARY13
GARY13 101 116455
GARY13 107 190098
GARY13 109S 236960
GARY14
GARY14 101 352869
GARY14 107 44013
GARY14 109S 14455
GARY15
GARY15 101 132265
GARY16
GARY16 101 362025
GARY16 107 94693
GARY16 109S 166565
GEMM11
GEMM11 101 321882
GEMM11 107 1637
GEMM11 115 617.
GEMM12
GEMM12 101 751085
GEMM12 109S 900285
GEMM12 124SB 176497
GEMM13
GEMM13 101 325656
GEMM13 107 30877
GEMM13 109S 20080
GEMM13 124SB 40281
GFRY12
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
101
107
1078
109S
124S8
New Service kWhFeeder Rate
GFRY12 101
GFRY13
GFRY13 101
GFRY13 107
GFRY13 109S
GGRU11
GGRU11 101
GGRU11 107
GGRU11 109S
GGRU12
GGRU12 101
GGRU12 107
GGRU12 124S
GGRU12 124S8
GOWN41
GOWN41 101
GOWN41 109S
GOWN42
GOWN42 109S
GRVE11
GRVE11 101
GRVE12
GRVE12 101
GRVE12 107
GRVE12 109P
GRVE12 119P
GRVE15
GRVE15 101
GRVE15 109S
GRVE16
GRVE16 101
GRVE18
GRVE18 101
GRVE18 107
GRVE18 109P
GRVE18 109S
GRVE22
GRVE22 107
GRVE22 109S
HAL Y11
HAL Y11
HAL Y11
HAL Y11
HAL Y11
HAL Y11
32156
1515
12438
782240
21805
31523
40214
111421
4778
17075
42253
17258
187806
1519160
20653
221672
19223
3711477
28047226
7051
38441
237615
13180
1662
3599743
1229840
83880
603482
136035
28200
3404
33810
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
HALY12
HAL Y12 101 725398
HAL Y12 \07 325405
HAL Y12 109S 236064
HAL Y14
HAL Y14 101 396564
HAL Y14 107 71488
HAL Y14 109S 32894
HAL Y14 124SB 3370
HAL Y15
HAL Y15 101 418404
HAL Y15 107 1732
HAVN42
HBND32
HBND32 101 440851
HBND32 107 37469
HBND32 124SB 2018
HBND33
HBND33 101 21622
HBND41
HBND41 101 720349
HBND41 107 116888
HBND41 109S 622581
HBND41 115 4692
HBND42
HBND42 101 353261
HBND42 107 16531
HBND42 115 419.
HDLK11
HDLK11 101 42549
HDSP11 106
HDSP11 101 1293400
HDSP11 107
HDSP12 107 70140
HFWY11
HFWY11 001 55943
HFWY12
HFWY12 001 105929
HFWY12 007 5494
HFWY12 015 782
HGSN11
HGSN11 101 60991
HGSN11 124SB 48778
HGSN12
HGSN12 101 58258
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
HGSN12 124S8 596371
HGSN13
HGSN13 101 45186
HGSN13 107 32194
HGSN13 124S8 87415
HGSN13 140 690.
HGTN11
HGTN11 007 12982
HGTN12
HGTN12 001 71763
HILL 11
HILL 11 107 6395
HILL 12 196
HILL 12 101 122 1140228
HILL 12 107 111202
HILL 13
HILL 13 101 417520
HILL 13 107 1760
HILL 14 198
HILL 14 101 819181
HILL 14 107 65757
HILL 14 109S 1234555
HILL 15
HILL 15 101 218916
HILL 15 107 12557
HILL 15 109S . 4373840
HLND11
HLND11 101 670985
HLND12
HLND12 101 20362
HLND12 107 40696
HLND13
HLND13 101 23489
HLND13 107 62234
HLND13 109S 80705
HMDL 11
HMDL 11 101 229736
HMDL 11 107 11786
HMDL 11 109S 15323
HMDL 11 124S8 121680
HMDL 12
HMDL 12 101 682077
HMDL 12 124S 27914
HMDL 12 124S8 169898
HMDL 12 001 16340
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
HMDl 13
HMDl 13 101 115847
HMDl 13 107 121566
HMDl 13 109S 4510
HMDl 13 124S8 30868
HMDl 14
HMDl 14 101 225198
HMDl 14 124S 3997
HMDl 14 124S8 73793
HOl Y11
HOl Y11 001 135242
HOl Y11 007 40977
HOl Y13
HOl Y13 001 30255
HOl Y13 007 5648
HOPE11
HOPE11 001 114875
HOPE11 024S8 8300
HRPR11
HRPR11 001 10864
HRPR12
HRPR12 007 20265
HRPR12 024S8 110510
HSTN 11
HSTN 11 101 538515
HSTN11 124S8 6123
HSTN12 101 36448
HSTN12 107 10267
HSTN13
HSTN13 101 65574
HSTN13 124S8 12551
HTHl 11 101 1642
HUlN13
HUlN13 101 155056
HUlN13 107 4129
HUlN13 109S 19755
HYDA41
HYDA41 101 81037
HYDA41 107 28740
HYDA41 109S8 58069
HYDA41 124C8 3220
HYDA41 124S8 494191
HYDA42
HYDA42 101 607861
HYDA42 107 43018
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
HYDA42 124CB 7168
HYDA42 124SB 193494
HYDA43
HYDA43 101 286308
HYDA43 107 72200
HYDA43 109S 388257
HYDA43 109SB 53689
ILND11 109S 85640
ILND12 101 876
ILND13
ILND13 124SB 852
JKSN41 101 8518
JMSN11
JMSN11 001 210987
JMSN11 007 2030
JMSN11 024SB 114278
JMSN12
JMSN12 001 400
JMSN12 007 1742
JMSN12 024SB 17586
JNCN41
JNCN41 101 5930
JNCN41 124SB 124260
JNCN42
JNCN43
JNCN43 124SB 120838
JNTA11
JNTA11 001 38117
JNVY11
JNVY12
JNVY31
JNVY31 001 122997
JNVY31 024SB 2242
JPLN11
JPLN11 101 12655
JPLN11 107 14303
JPLN11 124S 9933
JPLN12
JPLN12 101 18541
JPLN12 107 5314
JPLN13
JPLN13 101 82018
JPLN13 107 34253
JROM11
JROM11 101 15893
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
JROM11 107
JROM11 124SB
JROM12
JROM12 101
JROM13
JROM13 101
JROM13 107
JROM13 109S
JROM13 124CB
JROM14
JROM14 101
JROM14 107
JROM15
JROM15 107
JROM15 109SB
KCHM11
KCHM11 101
KCHM11 107
KCHM12
KCHM12 101
KCHM12 107
KCHM12 109S
KCHM13
KCHM13 101
KCHM13 107
KCHM14
KCHM14 101
KCHM14 107
KCHM16
KCHM16 101
KCHM16 107
KCHM16 109S
KCHM17
KCHM17 101
KCHM17 109SB
KNYN11 1245B
KNYN12
KNYN 13
KNYN13 107
KRMR41
KRMR41 101
KRMR41 1245
KRMR41 124SB
KRMR42
KRMR42 101
New Service kWh
8188
32381
249345
22948
21262
68515
8817
141119
67852
39464
28315
395987
31651
121093
31044
603979
175801
38118
161605
19144
685255
70332
36901
219360
10232
239449
968
2792
63324
52695
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder () and Rate CD () between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
KRMR42 107 31486
KRMR42 109S 229560
KRMR42 124S
KRMR42 124S8 1942
KRMR43
KRMR44
KUNA11 132
KUNA11 101 1340555
KUNA11 107 135340
KUNA11 109S 128320
KUNA11 115 18906
KUNA11 124S8 23379
KUNA12 151
KUNA12 101 887212
KUNA12 107 29437
KUNA12 109S 183680
KUNA13
KUNA13 101 499284
KUNA 13 107 10744
KUNA13 109S 43803
KUNA13 124S8 46231
LAKE11
LAKE11 124S8 153521
LAKE12
LAKE12 124S8 13910
LCNS11
LCNS11 101 202093
LCNS11 107 22192
LCNS11 124S
LCNS11 124S8 459936
LCST41 120
LCST 41 101 1139097
LCST 41 107 65212
LCST 41 109S 35582
LCST 42 213
LCST 42 101 176 2997554
LCST 42 107 335342
LCST 42 109S 1051395
LCST42 124S8 21442
LCST 43 230
LCST 43 101 149 1628319
LCST 43 107 163211
LCST 43 109S 3073651
LCST 44 817
LCST 44 101 767 9946335
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
LCST44 107 158537
LCST 44 109S 137160
LCST 44 140 2392
LIME12 007 4434
LKFK41 120
LKFK41 101 1071961
LKFK41 107 64991
LKFK41 109S 1253160
LKFK42
LKFK42 101 380843
LKFK42 107 77958
LKFK42 109S 119889
LMHI41
LMHI41 101 9080
LMHI42
LMHI42 101 128626
LMHI42 107 2115
LMHI42 124S8 13179
LNDN11
LNDN11 101 13850
LNDN11 107 107213
LNDN11 109S 190146
LNDN12
LNDN12 101 14086
LNDN12 107 8760
LNDN13
LNDN13 101 143475
LNDN13 107 6328
LNDN14 147
LNDN14 101 1032384
LNDN14 107 184133
LNDN14 109S 144023
LNDN14 115 699.
LNDN15 200
LNDN15 101 923574
LNDN15 107 27969
LNDN18 208
LNDN18 101 145 1602870
LNDN18 107 77929
LNDN18 109S 370105
LNDN18 124S8 17571
LNSG11
LNSG11 101 519850
LNSG11 107 9124
LNSG12
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
lNSG12 101 181292
lNSG12 109S 103407
lNSG13
lNSG13 101 843950
lNSG13 107 72670
lNSG 13 109S 46108
lNSG14
lNSG14 101 1101466
lNSG14 107 29995
lNSG14 124SB 61316
MCAl 11
MCAl 11 101 372933
MCAl 11 107 3409
MCAl 11 109S 45590
MCAl 11 115 225.
MCAl 12
MCAl 12 101 78091
MCAl 12 \07 43504
MCAl 12 109S 59550
MCAl 12 115 1007.
MCAl41 121
MCAl41 101 137 1762791
MCAl41 \07 67671
MCAl41 109S 175346
MCAl41 115 1564
MCAl42
MCAl42 \01 411090
MCAl42 109S 69704
MCAl42 115 442
MDRS11 150
MDRS11 101 906215
MDRS11 \07 98941
MDRS12 226
MDRS12 101 241 2765452
MDRS12 107 17106
MDRS12 \09S 875263
MDRS13 145
MDRS13 101 677 402
MDRS13 107 5113
MDVA11
MDVA11 101 118503
MlBA11
MlBA 11 101 23252
MlBA 11 107 97120
MlBA11 109P 2531226
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder () and Rate CD () between (1/01/2004 and 11/30/2005)
Feeder Rate
MLBA 11 109S
MLBA12
MLBA 12 101
MLBA 12 107
MLBA 12 107B
MLBA 12 109S
MLBA12 115
MLBA 12 124SB
MLNR41 101
MLNR41 107
MLNR41 124SB
MLNR42
MLNR42 101
MLNR42 107
MLNR42 109S
MLNR42 124S
MLNR42 124SB
MLNR43
MLNR43 124SB
MNHM11
MNHM11 107
MNHM12
MNHM12 101
MNHM12 107
MNHM12 109S
MNHM13
MNHM13 101
MNHM13 107
MOON41
MOON41 101
MOON41 107
MOON41 109S
MOON41 124SB
MOON42
MOON42 101
MOON42 107
MOON42 109S
MOON42 124CB
MOON42 124SB
MORA41
MORA41 101
MORA41 107
MORA41 109S
MORA41 115
MORA41 124SB
New Service kWh
93427910 16 592898
215476
1168760
7620
25778
2977
651000
67667
808
178068
348461
7853919
860150 100 1140470
19313
10952329
124592
2491430 21 155797
14238
428230
1069627 21 320372
20409
312968
586
29737290 238 3272749
81113
110261
2 1369.
89507
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
MORA42
MORA42 101 148687
MORA42 107 30312
MORA42 109S 1000560
MORA42 124S8 1214240
MORA43
MORA43 101 143631
MORA43 107 11907
MORA43 109S 20080
MORA44 387
MORA44 101 239 2570854
MORA44 107 48293
MORA44 109S 106449
MORA44 166
MORA45 202
MORA45 101 134 1652067
MORA45 107 27286
MORA45 109S 124388
MPRK11
MPRK11 101 45080
MPRK11 107 3973
MPRK11 109S 562882
MPRK11 124S8 2323
MR8T41 024S8 58520
MRDN11
MRDN11 101 456433
MRDN11 107 211909
MRDN11 109S 717016
MRDN12 224
MRDN12 101 287121
MRDN12 107 11780
MRDN12 109S 321918
MRDN13
MRDN13 101 79213
MRDN13 107 33468
MRDN13 109P 1651931
MRDN13 109S 1001463
MRDN13 119P 10644979
MRDN14
MRDN14 107 107769
MRDN14 109S 429160
MRDN15
MRDN15 101 700162
MRDN15 124C8 1095
MRDN16
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
MRDN16 101
MRDN16 107
MRDN16 109S
MRLD11
MRLD11 101
MRLD11 124SB
MRLD41
MRLD41 101
NHBT11
NHBT11 101
NHBT11 124SB
NHBT12
NHBT12 124SB
NMPA11
NMPA11 101
NMPA14
NMPA14 101
NMPA14 107
NMPA14 109S
NMPA14 142M
NMPA15
NMPA15 101
NMPA15 107
NMPA15 109S
NMPA16 101
NMPA16 107
NMPA17 107
NMPA17 109S
NMPA19
NMPA19 101
NMPA19 107
NMPA19 109S
NMPA20
NMPA20 101
NMPA20 107
NMPA20 109S
NMPA20 115
NMPA20 124SB
NMPA21
NMPA21 107
NMPA21 109S
NMPA22
NMPA22 101
NMPA22 107
NWMS41
New Service kWh64 812279
161191
321321
44188
48592
115819
25607
116688
466911 9601116 33 284492
84528
1121268
3700
20484
138123
117361
1984
14594
12760
35469149 176 1916347
118998
220508024 39 77069711 117530
2811384
56544
16481
32003
8744626 50 487191
560233
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
NWMS41 101 625167
NWMS41 107 140668
NWMS41 109S 82800
NWMS42
NWMS42 100 18221
NWMS42 101 225656
NWMS42 107 63621
NWPM11
NWPM11 101 385197
NWPM11 107 12075
NWPM11 109S 582040
NWPM11 124SB 109645
NWPM12
NWPM12 101 414164
NWPM12 107 13360
NWPM12 124SB 6186
NWPM13 101 34687
NWPM13 107 49210
NWPM13 109S 195173
NYSA 11
NYSA 11 001 32891
NYSA 11 007 113332
NY SA 11 009S 639680
NYSA 12
NYSA 12 101 172744
NYSA12 107 2421
NYSA12 109S 3101222
NYSA12 124SB 464
NYSA 13
NYSA 13 001 377 487
NYSA 13 007 19222
NYSA 13 024CB 23228
NY SA 13 024SB 422366
NYSA14
NYSA14 007 34124
OCHD41
OCHD41 101 41672
OCHD41 107 12915
0lDA11
0lDA11 007 51362
0lDA11 009S 3548164
0lDA11 009SB 467
OKL Y11
OKL Y11 101 11709
OKL Y11 107 6666
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
OKL Y12
OKL Y12 101 199
OKL Y13
OKL Y13 101 10878
OKL Y13 107 7761
OLAA11
OLAA11 101 21265
OLAA11 124CB 3061
OLAA 11 124SB 14095
ONT014
ONT014 101 14692
ONT014 107 1139
ONT015
ONT015 101 49373
ONT018
ONT018 001 2713
ONT019
ONT019 001 413262
ONT019 007 1032
ONT019 0095 49367
ONT020 001 61094
ONT020 007 77726
ONT020 0095 326149
ONT023
ONT023 101 104180
ONT023 107 6979
ONT023 001 8677
ONT024
ONT024 107 30087
ONT024 001 392565
ONT024 007 4971
ONT024 009SB 163080
ONT024 015 4498.
ONT024 024SB 19257
ONT025
OYDM 11
OYDM11 007 24932
PAET11
PAET11 101 131201
PAET11 107 120598
PAET11 1095 5461
PAET12
PAET12 101 455576
PAET12 107 12984
PAET12 1095 2211013
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder () and Rate CD () between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
PAET12 115 2306
PAET12 124CB 5767
PAET12 124SB 15936
PAET13
PAET13 101 441821
PAET13 107 79896
PAET13 109S 461783
PAET13 124S8 54808
PAUL41
PAUL41 107 17048
PAUL41 124SB 313410
PAUL42 101 35182
PAUL42 107 4682
PAUL44 101 78614
PNCK11
PNCK11 001 7479
PNCK12
PNGE41
PNGE41 101 58325
PNGE41 124CB 9463
PNGE42
PNGE42 101 130826
PNGE42 107 8797
PNGE42 1078 4129
PNGE42 124S8 195749
PNGE43
PNGE43 101 58495
PNGE43 107 18380
PNGE43 124SB 55471
PNUF41
PNUF41 101 138118
PNUF42
PNUF42 101 247370
PNUF42 107 12044
PNUF42 124SB 51681
POC011
POC011 101 12768
POC011 107 22276
POC012 101 21007
POC013
POC013 101 178842
POC013 107 8303
POC014
POC014 101 8759
POC014 107 68430
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
POC014 109S 9080
POC015
POC015 101 31845
POC015 107 15548
POC016
POC016 107 60315
PRIN11
PRIN12
PRIN12 107 31124
PRMA11
PRMA 11 101 133587
PRMA 11 107 6832
PRMA11 109S 4221520
PRMA12
PRMA12 101 230010
PRMA12 107 2957
PRMA12 109S 489456
PRMA12 124SB 69040
PRMA41
PRMA41 101 594001
PRMA41 107 122306
PRMA41 109S 219963
PRMA41 124SB 234551
PRMA42
PRMA42 101 215543
PRMA42 107 22695
PRMA42 124SB 29569
PRMA42 001 108510
PTVY 41
PTVY 41 109S 261000
PTVY 42
PTVY 42 107 50329
PTVY 42 109S 188253
PTVY 43
RKFD11 101 4459
RKFD12 101 13133
RKFD12 109S 699922
RKFD13
RKFD14
RKFD14 101 30165
RKVL 11 001 49833
RSET11
RSET11 101 35654
RSET11 107 742
RSET11 107B 4031
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
RSFK12
RSFK12 101 56727
SAMN12
SAMN12 101 197281
SAMN12 107 93200
SAMN12 124SB 5985
SAMN13
SAMN13 101 19362
SAMN13 107 93673
SAMN13 109S 568929
SAMN14
SAMN14 101 247383
SAMN14 107 117274
SAMN14 109S 1225453
SAMN41
SAMN41 101 223287
SAMN41 107 209452
SAMN41 115 340
SAMN41 124CB 107
SAMN42
SAMN42 101 406918
SAMN42 107 197589
SAMN42 109S 224578
SAMN42 124SB 5867
SCOT11 101 12469
SCSU42
SCSU42 101 21523
SHSH11
SHSH11 101 98654
SHSH12
SHSH12 101 592971
SHSH12 107 62960
SHSH12 124SB 73419
SIPN41 257
SIPN41 101 115 718080
SIPN41 107 64771
SIPN41 109S 1007437
SIPN42
SIPN42 101 393674
SIPN42 107 65665
SIPN42 109S 753600
SIPN42 124SB 70253
SIPN43
SIPN43 101 359630
SIPN43 107 110
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
SLVR41
SLVR41 101 350533
SL VR41 107 71474
SL VR41 124S8 69698
SL VR42
SL VR42 101 33340
SL VR42 124S8 5900
SMFY11 101 426
SMFY12 101 26550
SOPK11
SOPK11 101 86398
SOPK11 109S 420148
SOPK12
SOPK12 101 201147
SOPK12 107 3299
SOPK12 124S8 99865
SRCK42
SRCK42 101 209461
SRCK42 107 2320
SRCK42 115 563.
SRCK42 124S8 89079
STAR11
STAR11 101 550582
STAR11 124S8 24825
STAR12 349
STAR 12 101 110 1236653
STAR 12 107 117623
STAR 12 109S 23981
STAR13
STAR13 101 220011
STAR13 107 46961
STAT11
STAT11 101 697117
STAT11 107 16041
STAT 12
STAT12 101 161489
STAT12 107 10942
STAT13
STAT13 101 44962
STAT13 107 579
STAT14 101 20468
STAT14 107 120206
STAT14 109S 168475
STAT15
STAT15 101 122452
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
STAT15 107 93754
STAT15 109S 71632
STAT16
STAT16 101 25011
STAT17
STAT17 101 343875
STAT17 107 875
STRD11 371
STRD11 101 310 2084728
STRD11 107 97863
STRD11 109S 1587434
STRD12
STRD12 101 110 1891890
STRD12 107 13096
STRD12 124CB 5989
TERY12
TERY12 101 103766
TERY12 107 59595
TERY14
TERY14 101 109174
TERY14 107 231
TERY15
TERY15 101 156439
TERY15 107 63671
TERY15 109S 635160
TERY16
TERY16 101 47001
TERY16 109P 655320
TERY16 109S 96084
TFSN12
TFSN12 101 301427
TFSN12 107 57174
TFSN13 138
TFSN13 101 429961
TFSN13 107 17373
TFSN13 109S 32538
TFSN14
TFSN14 101 231339
TFSN14 107 42551
TFSN15
TFSN15 101 21460
TFSN15 107 28073
TFSN16
TFSN16 101 15767
TFSN17
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected , it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
TFSN17 101 181091
TFSN18
TFSN18 101 25676
TFSN18 107 195043
TFSN18 1078 19198
TFSN18 109S 112611
TFSN19 101
TFSN19 101 158 836603
TFSN19 107 155434
TFSN19 109S 78772
TFSN20
TFSN20 101 70407
TFSN20 107 190337
TFSN20 109S 417853
THCK11 101 33255
TMRK11
TMRK11 101 34480
TNDY11
TNDY11 101 164969
TNML 11 188
TNML 11 101 289 3329071
TNML 11 109S 67088
TNML 12
TNML 12 101 1024904
TNML 12 107 2483
TNML 12 109S 50660
TNML 13 286
TNML 13 101 123 1687457
TNML 13 107 29002
TNML 13 109S 217240
TNML 14 111
TNML 14 101 1060074
TNML 14 107 5628
TOPN41
TOPN41 101 239838
TOPN41 107 53696
TOPN41 124S8 238837
TOPN42
TOPN42 101 50218
TOPN42 107 12936
TOPN42 109S 152742
TOPN42 124S8 93404
TYHE11
TYHE11 101 82860
TYHE12
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
TYHE12 101 95224
TYHE12 107 6788
UNTY11 007 757
UNTY12
UNTY12 001 134633
UNTY12 007 7385
UNTY12 0078 210
UNTY12 015 1552.
UNTY12 024S8 1973
USTK11
USTK11 101 301992
USTK11 107 8791
USTK11 109S 2772
USTK12
USTK12 101 248322
USTK12 107 33793
USTK13
USTK13 107 937
USTK14 107 2483
USTK15
USTK15 101 250462
USTK15 107 61211
USTK16
USTK16 101 32359
USTK16 107 15073
USTK17
USTK17 101 43223
USTK17 107 18547
USTK17 109S 32456
USTK18
USTK18 101 388
USTK18 107 76445
USTK18 109P 3197763
USTK18 109S 268589
VALE11
VALE11 001 95141
VALE11 007
VALE11 009S 671100
VALE11 015 3041.
VALE11 084C 16440
VALE11 084CS 103309
VALE13
VALE13 001 106910
VALE13 007 1187
VALE13 024S8 62021
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate New Service kWh
VALE14
VALE14 001 107970
VALE14 009S 513068
VALE14 024S8 8884
VALE15
VALE15 001 37838
VALE15 007 10217
VALE15 024S8 63014
VLVU11
VLVU11 101 241825
VLVU11 107 12010
VLVU11 109S 730164
VLVU12 111
VLVU12 101 114 1109946
VLVU12 109S 133580
VLVU13
VLVU13 101 411145
VLVU13 107 65332
VLVU13 109S 75300
VfRY11
VfRY11 101 66463
VfRY11 107 44291
VfRY11 109S 77840
VfRY12
VfRY12 101 146 1727935
VfRY12 107 113442
VfRY12 109S 60231
VfRY13
VfRY13 101 77362
VfRY13 107 5733
VfRY14
VfRY14 101 1852
VfRY14 109S 153
VfRY15
VfRY15 101 19186
VfRY15 107 33671
WARE11
WARE11 101 159899
WARE11 109S 111832
WARE11 124S8 10086
WBUT11
WBUT11 124S8 322053
WESR11
WESR11 101 190306
WESR 11 107 8960
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
WESR11 115
WESR11 124S8
WESR 12
WESR12 101
WESR 12 124S8
WESR13
WESR13 001
WESR14
WESR14 101
WESR14 124S8
WNDL 11 109S
WNDL 12
WNDL 12 101
WNDL 12 107
WNDL 12 124S8
WNDL 13
WNDL 13 101
WNDL 13 107
WNDL 13 124S8
WWCK11 101
WWCK11 115
WWCK11 124S8
WWCK12
WWCK12 101
WWCK12 107
WWCK12 109S
WWCK12 115
WWCK12 124S8
WYEE11
WYEE11 101
WYEE13
WYEE13 107
WYEE14
WYEE14 101
WYEE14 107
WYEE15 107
WYEE15 109S
WYEE16
WYEE16 107
WYEE17 107
WYEE17 109S
WYEE17 115
WYEE18
WYEE18 101
WYEE18 107
New Service kWh
782
59337
127454
7899
116467
68142
4444
122580
172566
10855
5221
88067
5137
24203
139096
402.
26016
256524
37616
325160
1524
16594
48814
93714
8370
6058
44399
133372
31622
33047
491686
1396.
51214
9935
Service Points counts are counts of the premises within the Feeder/Rates.
If a premises changed Rate Codes within the time period selected, it is counted within
each Feeder/Rate
Feeder ( ) and Rate CD ( ) between (1/01/2004 and 11/30/2005)
Feeder Rate
WYEE18 1095
WYEE 19
WYEE19 107
ZLOG15
ZLOG15 101
ZLOG15 107
ZLOG15 1095
ZLOG15 115
ZLOG16
ZLOG16 101
ZLOG16 107
ZLOG16 1095
ZLOG17
ZLOG17 101
ZLOG17 1095
ZLOG18
ZLOG18 101
ZLOG18 1095
New Service kWh
1922886
6797949 22 36567117 185060
46080
1 452.33 67 768157
29202
44862313
49789
220708
14803
908560
TOTALS 32977 237652679
c:~:; i~ Ii
IDAHO POWER COMPANY . t.e
, ,--
CASE NO. IPC-O5-28
UTILi: i'~::; l: hlSS10N
FIRST PRODUCTION REQUEST
OF THE IDAHO IRRIGATION
PUMPERS ASSOCIATION, INC.
TT A CHMENT TO
RESPONSE TO
REQUEST NO.
1st Production Request of Irrigation Pumpers
Response to Request No.
Agricultural Service Schedules
Normalized kWh
Idaho Jurisdiction System
kWh kWh Total kWh
Year Month Rate 24 Rate 25 ricultural
2003 Jan 935,984 219 980 858
Feb 863 810 256 895 637
Mar 247 105 895 351 166
Apr 682,708 395 641 359 229
May 109 170,402 182 312 120 144 136
Jun 242 809 305 846 794 263,354 774
Jul 393 361 074 652 898 422 152 632
Aug 362 537,499 18,668 307 392 208 373
Sep 277 813 952 990 916 299 725 365
Oct 126 267 276 009 744 134 367 821
Nov 420 865 838 713 275 854
Dec 330 525 353 157 753 900
2004 Jan 805 097 102 848 356
Feb 769 567 278 800 261
Mar 015 202 780 179 820
Apr 122 883 261 332 590 303
May 127 905,499 5,476,464 138 626 263
Jun 257 725 264 065 373 277 367 803
Jul 381 788 604 980 599 406 876,408
Aug 351 080 774 908,421 376 810 778
Sep 270,493 991 688 164 289 790 656
Oct 139 389 184 228 603 148,403 935
Nov 627 033 796 394 088 646
Dec 637 453 521 1,701 586
2005 Jan 805 097 102 848 356
Feb 769 567 278 800 261
Mar 014 302 780 178 920
Apr 625 451 153 313 984 852
May 124 988,433 2,488,464 132 721 197
Jun 255 279 892 568,541 270,425 599
Jul 376,732 565 128 886 394 968 656
Aug 346,831 961 5,497 132 365 150 676
Sep 267 265,577 354 587 280 228 665
Oct 137 995 026 351,409 145 210 267
Nov 160 126 420 384 289,262
Dec 634 723 521 698 856
: .
~ i \/ E D
IDAHO POWER COMPANY ? I
;;
3: If
CASE NO. IPC-O5-
iIT!i!';;;c n""
c..i;;:JL,Uril;/SSIOFi
;;/
FIRST PRODUCTION REQUEST
OF THE IDAHO IRRIGATION
PUMPERS ASSOCIATION, INC.
ATTACHMENT TO
RESPONSE TO
REQUEST NO.
st Production Request of Irrigation Pumpers
Response to Request No.
Agricultural Service Schedules
Normalized MWh
Idaho Jurisdiction - MWh
Year Month Rate 24 Rate 25 Total
2003 Jan 893 899
Feb 993 999
Mar 590 208 798
Apr 631 264 895
May 200 318 681 209,999
Jun 346 306 804 364 110
Jul 390,808 575 408 383
Aug 311 614 531 327 145
Sep 172 271 957 181 228
Oct 53,675 2,454 129
Nov 759 440 199
Dee 623 100 723
Total 543,481 026 619 507
2004 Jan 779 783
Feb 793 799
Mar 634 727
Apr 820 875 78,695
May 219 032 012 227 044
Jun 332,689 583 344 272
Jul 381 917 665 395,582
Aug 311 264 11,461 322 725
Sep 177 363 754 183,117
Oct 60,455 799 254
Nov 586 182 768
Dee 033 039
Total 568 365 56,440 624 805
2005 Jan 779 783
Feb 792 798
Mar 277 332
Apr 938 170 108
May 205 872 809 209 681
Jun 354,455 838 360,293
Jul 378 257 018 384 275
Aug 306,883 930 311 813
Sep 185,443 234 188,677
Oct 46,853 825 678
Nov 520 104 624
Dee 034 039
Total 548,103 998 574 101
. c ,10' L: D
IDAHO PO WE RC 0 MP ANY
;:?
?~; 3: LB
CASE IPC QI' '
. .::'- -
Lj::c.~,t,--'iil-;;) I
~:~-
FIRST PRODUCTION REQUEST
OF THE IDAHO IRRIGATION
PUMPERS ASSOCIATION, INC.
TT A CHMENT TO
RESPONSE TO
REQUEST NO.
lalOho Power Company
Date of Report
(Mo, Da. Yr)
04/30/2001
Year of Report
Dec. 31 2000
. .-oo- ", ""...."oo""".
. II the re!pondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
2, Rt-port In column (b) the system s energy output for each month such that the total on Line 41 matches the total on Line 20.
3, Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any
flnergy losses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated) in
milking the Non-Requirements Sales for Resale.
. Report In column (d) the systems monthly maximum megawatt Load (60-minute integration) associated with the net energy for the system defined as
the difference between columns (b) and (c)
!J. Report in columns (e) and (f) the specified information for each monthly peak load reported in column (d).
NAME OF SYSTEM:
line Monthly Non-Requirments MONTHL Y PEAKSales for Resale &No.Month 10tal Monthly Energy Associated Losses Megawatts (See Instr. 4)Day of Month Hour
(a)(b)(c)(d)(e)(f)
January 800 500 460.817 266 9AM
February 577 .869 428.490 132 8AM
March 822.332 643 365 978 8AM
April 919.411 791 457 000 4 PM
May 686.089 338.~90 253 10 PM
June 818.574 220,719 799 8PM
July 970,723 259.142 919 5PM
August 849 104 284 .891 746 5PM
September 687,441 472.823 418 7 PM
38 October 361 903 287 617 898 8AM
39 November 394 033 131 368 179 8AM
40 December 500,753 158,150 091 8PM
TOTAl 20,388,732 477 ,429 ~f~~~~!,\:j1~,~;fr;if ~j:
: ~:
:J_t\~'\f;i ~:f;;rB)Jj~~iF~'
~ ," ,., ',: /,
;!~%tjt~~i~;;fi
FERC FORM NO.1 (ED. 12-90)Page 401b
Name of Respondent This
~~
Is:Date of Report Year of Report
Idaho Power Company
(1) X An Original (Mo. Da, Yr)Dec. 31 2001(2) A Resubmission 04130/2002
MONTHLY PEAKS AND OUTPUT
If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-
integrated system.
Report in column (b) the system s energy output for each month such that the total on Line 41 matches the total on Line 20.
rt in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any
ene,
... ,
asses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated) in
making the Non-Requirements Sales for Resale.
Report in column (d) the system s monthly maximum megawatt Load (60-minute integration) associated with the net energy for the system defined as
the difference between columns (b) and (c)
Report in columns (e) and (f) the specified information for each monthly peak load reported in column (d).
NAME OF SYSTEM:Idaho Power System Load
Line
Monthly Non-Requirments MONTHLY PEAK
Sales for Resale &
No.Month Total Monthly Energy Associated Losses Megawatts (See Instr. 4)Day of Month Hour
(8)(b)(c)(d)(e)(f)
January 601 850 245.496 299 8AM
February 180,648 730 345 8AM
March 340 827 229,445 084 8AM
April 191 295 174 545 868 8AM
May 395,732 170,135 305 7 PM
June 477,599 167,014 496 6PM
July 661,114 260.976 570 7 PM
August 648.932 224 177 543 7 PM
September 341 171 233.758 102 5 PM
October 208,896 165.430 774 8AM
November 282.616 225.981 059 7 PM
4'" "'Iecember 431 282 194 278 030 8AM
......
TOTAL 16,761 962 296.965 \. ~):;:.::;;:;; :';~~:i:::~:;:'f\;i.~f?;:lA~~;?;;::';i::\:\';:!
~~~:;\;;
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FERC FORM NO.1 (ED. 12-90)Page 401b
Name ot Respondent This I'~ort Is:Date 01 Report Year 01 Report
Idaho Power Company
(1) X An Original (Mo, Da, Yr)Dec. 31,2002
(2) n A Resubmission 04/30/2003
rll10NTHLY PEAKS AND OU1PUl
II the respondent has two or more power systems which are not physically integrated, lurnish the required inlormation lor each non. integrated system.
Report in column (b) the system s energy output lor each month such that the total on line 41 matches the total on Line 20.
Report in column (c) a monthly breakdown 01 the Non-Requirements Sales For Resale reported on line 24.include in the monthly amounts any
energy losses associated with the sales so that the total on Line 41 exceeds the amount on line 24 by the amount
01 losses incurred (or estimated) in
making the Non.Requirements Sales lor Resale.
Report in column (d) the system s monthly maximum megawatt Load (60--minute integration) associated with the net energy for the system defined as
the difference between columns (b) and (c)
Report in columns (e) and (I) the specilied inlormation tor each monthly peak load reported in column (d).
NAME OF SYSTEM:
line
Monthly Non-Requirments MONTHLY PEAK
Sales lor Resale &
No.Month 10ta1 Monthly Energy Associated Losses Megawatts (See Instr. 4)Day 01 Month Hour
(a)(b)(c)(d)(e)(f)
January 614 296 418,746 131 8AM
February 165,978 112,210 074 8AM
March 310,521 260,652 917 8AM
April 161 689 207 684 719 BAM
May 314 295 136,529 365 5 PM
June 454 941 63,697 822 4 PM
July 687,221 86,813 963 4 PM
August 504 329 110,695 529 6PM
September 291,805 165,481 310 6PM
October 218,042 164,615 934 8AM
39 November 125,493 62,902 912 8 AM
40 December 343,781 172,198 942 7 PM
TOTAL 16,192,391 962,222 ~n~~~~~~~~~/: ;:~t;:'E;,
;'$.
iif411t~;3~ff&jtf,i\j
~::' :;,":'
:A/!Y';;t~~~;BUt
Name of Respondent
Idaho Power Company
Year of Report
Dec. 31 2003
This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)
(2) A Resubmission 04/30/2004
MONTHLY PEAKS AND OUTPUT
1. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
2. Report in column (b) the system s energy output for each month such that the total on Line 41 matches the total on Line 20.
3. Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any
energy losses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated) in
making the Non-Requirements Sales for Resale.
4. Report in column (d) the system s monthly maximum megawatt Load (60-minute integration) associated with the net energy for the system defined as
the difference between columns (b) and (c)
5. Report in columns (e) and (I) the specified information for each monthly peak load reported in column (d).
NAME OF SYSTEM:Idaho Power Company - System Load
Line Monthly Non-Requirments MONTHLY PEAKSales for Resale &
No.Month Total Monthly Energy Associated Losses Megawatts (See Instr. 4)Day of Month Hour
(a)(b)(c)(d)(e)(f)
29 January 253,784 102 502 955 8AM
30 February 166,443 141,193 974 8AM
31 March 162 851 141,761 779 8AM
32 April 222,508 241 139 715 8AM
33 May 389,124 206,929 537 5PM
34 June 577,165 97,770 2;759 6PM
35 July 756,153 252 944 5PM
36 August 591,104 124 028 674 5PM
37 September 367 581 190,047 397 7PM
38 October 220,359 157,928 800 6PM
39 November 182,618 73,801 949 9AM
40 December 365,562 178,316 961 8AM
TOTAL 16,255,252 726,666
Name of Respondent This R
ooort Is:
Date of Report Year/Period of Report
Idaho Power Company
(1) X An Original (Mo, Da, Yr)End of 2004/04
(2) nA Resubmission 04/22/2005
MONTHLY PEAKS AND OUTPUT
(1 ) Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required
information for each non- integrated system.
(2) Report on line 2 by month the system s output in Megawatt hours for each month.
(3) Report on line 3 by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
(4) Report on line 4 by month the system s monthly maximum megawatt load (60 minute integration) associated. with the system.
(5) Report on lines 5 and 6 the specified information for each monthly peak load reported on line
NAME OF SYSTEM:IDAHO POWER COMPANY - SYSTEM LOAD
Line
Monthly Non-Requirments MONTHLY PEAK
Sales for Resale &
No.Month Total Monthly Energy Associated Losses Megawatts (See Insu. 4)Day of Month Hour
(a)(b)(c)(d)(e)(f)
January 334,017 72,251 196 7PM
February 258,704 140,373 072 8AM
March 455,063 431 459 877 8AM
April 370,496 335,462 758 9AM
May 1,493,443 302,534 109 7PM
June 750,724 315,058 843 5PM
July 780,638 191,534 825 6PM
August 683,160 221,018 792 6PM
September 525,329 353,612 395 5PM
October 173,703 99,934 735 8AM
November 202,388 106,834 063 8A~
December 433,510 210,950 033 7PM
TOTAL 17,461,175 781 019 ~JJIi1lfl~~~!fft~lt~~~fgi~.~~~~ ti~~~jJ;~KV;~t;!~~i~$.~~~\~ ~~i;:~~~; .
FERC FORM NO.1 (ED. 12-90)Page 401b
IDAHO POWER COMPANY
CASE NO. IPC-O5-
FIRST PRODUCTION REQUEST
OF THE IDAHO IRRIGATION
PUMPERS ASSOCIATION, INC.
ATTACHMENT TO RESPONSE TO
REQUEST NO. 23 IS CONFIDENTIAL
AND HAS BEEN FILED SEPARATELY
/;~u
ID AH PO WE R CO MP ANY :~: f;:J:1:8
CASE NO.IPC-O5-;!T ll:. l.. r:";i,
;;.
~I' .'.
;;"-
'-'01IJII .)1 j,
-:;;;.
FIRST PRODUCTION REQUEST
0 F THE ID AH 0 IRRI G A TI 0 N
PUMPERS ASSOCIATION, INC.
ATTACHMENT TO
RESPONSE TO
REQUEST NO. 24
(Intra-Company Correspondence)
Date:June 17 2005
To:Jeannette Bowman
From:Barr Smith
2005 Normalized EnergySubject:
The attached tables represent normalized sales in MWh by rate, jurisdiction, and month for the period
January 2005 to December 2005. Normalized sales are typically weather-adjusted sales when appropriate.
However, other adjustments are made to reflect more "normal" energy consumption levels. These
adjustments are described below.
ENERGY NORMALIZATION
Residential, Commercial, and Industrial Normalization
Normalized energy over the period January 2005 through May 2005 was set to weather-adjusted energy in
the residential and commercial classes. In the industrial class normalized energy over the period January
2005 through May 2005 was set to actual energy (adjusted for billing errors). Normalized energy over the
period June 2005 through December 2005 was set to the prior June 2004 through December 2004
normalized energy multiplied by escalation or growth factors. The escalation factors were calculated by
taking the percent change in weather-adjusted sales, comparing the 12-month period ending May 2005 to
the 12-month period ending May 2004. Normalized June 2004 through December 2004 residential energy
was increased by 2.932%, commercial by 3.048% and industrial by 1.369% to arrive at the June 2005
through December 2005 forecast of normalized energy.
Irrigation Normalization
Normalized energy for the irrigation class was based on the 2004 irrigation season. The adjusted 2004
actual energy, provided by Mary Mowrey, was utilized as the base to add weather adjustments in the
irrigation weather normalization procedure. Prior to weather normalization, the 2004 actual energy was
adjusted downward by the 2004 monthly sum of the individual Ben Rapids accounts for each rate class.
In 2004, Ben Rapids represented 50 288 598 kWh. No escalation or growth factor was applied to the
2004 weather-adjusted irrigation sales.
Normalization of Simplot Fertilizer Facility
Normalized energy for Simplot Fertilizer was set to January 2005 through May 2005 actual energy and
June 2005 through December 2005 forecast energy. A new Simplot Fertilizer energy forecast was
completed in June 2005 and was based on Simplot's latest short-term load projections.
Normalization of Micron Technology
Normalized energy for Micron Technology was set to January 2005 through May 2005 actual energy and
June 2005 through December 2005 forecast energy. A new Micron Technology energy forecast was
completed in June 2005.
Normalization of INL
Nonnalized energy for the INL was set to January 2005 through May 2005 actual energy and June 2005
through December 2005 forecast energy. The forecast energy figures were taken directly from a power
forecast received from the INL on May 24, 2005.
Normalization of City of Weiser
Nonnalized energy for the City of Weiser was set to January 2005 through May 2005 weather-adjusted
energy and June 2005 through December 2005 forecast energy. A new City of Weiser energy forecast
was completed in June 2005.
Normalization of Raft River Rural Electric Cooperative, Inc.
Nonnalized energy for Raft River Rural Electric Cooperative, Inc. was set to January 2005 through May
2005 weather-adjusted energy and June 2005 through December 2005 forecast energy. A new Raft River
energy forecast was completed in June 2005.
Normalization of Firm Off-System Customers
Nonnalized energy for the City of Cohon was set to zero since the City of Cohon s contract wi1l expire
on May 31 , 2005.
Normalization of Rate Transmission Service and Rate 19 Transmission Service Idaho Jurisdiction
The energy used by in June 2004 as "Schedule 9" transmission service was reclassified
as "Schedule 19" transmission service energy.
Normalization of Rate 19 Primary Service and Rate Primary Service Idaho Jurisdiction
The energy used by the following Schedule 19 customers that was previously classified as "ScheduJe 9"
primary service was reclassified as "Schedule 19" primary service energy.
The energy used by the following Schedule 9 customer that was previously classified as "ScheduJe 19"
primary service was reclassified as "Schedule 9" primary service energy.
Normalization of Rate 19 Primary Service and Rate 19 Transmission Service -Idaho Jurisdiction
The energy used by the folJowing Schedule 19 customers that was previously classified as Schedule 19
transmission service" was recJassified as Schedule 19 "primary service" energy. The four customers that
were recJassified are:
Normalization of Rate 15 - Dusk-to-Dawn Customer Lighting Residential- Oregon Jurisdiction
The energy booked in July 2004 (11 290 kWh) was unusually low compared to the surrounding months.
The "nonnalized" energy (14 996 kWh) was estimated by averaging the June 2004 and August 2004
booked energy figures. The energy booked in March 2005 (12 202 kWh) was unusually low compared to
the surrounding months. The "nonnalized" energy (14 749 kWh) was estimated by averaging the
February 2005 and April 2005 booked energy figures.
Normalization of Rate 16 - Dusk-to-Dawn Customer Lighting Commercial- Idaho Jurisdiction
The Idaho Schedule 16 lamps were adjusted to compensate for Simplot in Nampa who had been billed
for 6 lamps that were actually non-existent. These lamps were canceled for three years worth of billings
in December 2004. The "nonnalized" figures for June 2004 through November 2004 were the booked
figures, reduced by 341 kWh in each month. The "nonnalized" figure for December 2004 was the booked
figure plus 12 276 kWh.
Normalization of Rate 16 - Dusk-to-Dawn Customer Lighting Commercial- Oregon Jurisdiction
The energy booked in June 2004 (18 769 kWh) was unusually low compared to the surrounding months.
The "nonnalized" energy (20 876 kWh) was estimated by averaging the May 2004 and July 2004 booked
energy figures.
Normalization of Rate 32 - Street Lighting Service City of Ketchum -Idaho Jurisdiction
The energy booked in June 2004 as a Schedule 32 in the Idaho jurisdiction was combined into Schedule
, Idaho jurisdiction. Therefore, the Schedule 32 , Idaho jurisdiction nonnalized energy is zero.
Normalization of Rate 40 Un metered General Service Idaho Jurisdiction
The" energy figures booked in January 2004 through June 2004 were averaged. The resulting figure was
used in place of booked figures in each of the respective months to decrease the sales variability and to
more accurately reflect a more "nonnal" sales behavior.
Normalization of Rate 41 - Street Lighting Service Idaho Jurisdiction
The energy figures booked in June 2004 and November 2004 were averaged. The resulting figure was
used in place of booked figures in July, August, September, and October 2004 to decrease the sales
variability and to more accurately reflect a more "nonnal" sales behavior. The energy booked in January
2005 (1,540 136 kWh) was adjusted upward to 1 549 376 kWh t9 reflect a billing error.
Normalization of Rate 42 - Traffic Control Signal Lighting Service Idaho Jurisdiction
The energy figures booked in June 2004 through April 2005 were set to May 2005 booked energy
(642 098 kWh). The May 2005 figure was used in place of booked in each of the respective months to
more accurately reflect a more "nonnal" sales pattern.
CERTIFICATE OF SERVICE
:' ;~~! ,
" r:
I HEREBY CERTIFY that on this 21 st day of December, 2005;,iliseN~p Cf';J ?: !, true and correct copy of the within and foregoing IDAHO POWER COMPANY'' " .0
RESPONSE TO FIRST PRODUCTION REQUEST OF THE IDAHO IRRI~~TIQN -
PUMPERS ASSOCIATION upon the following named parties by the m~ih8~-ihi:fieat1:ili'ii"i!SSiON
below, and addressed to the following:
Donald L. Howell , II
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington Street
O. Box 83720
Boise, Idaho 83720-0074
don .howellcm.puc.idaho.qov
-L Hand Delivered
S. Mail
Overnight Mail
FAX [phone]
--x-E-mail
Randall C. Budge
Eric L. Olsen
Racine , Olson , Nye, Budge & Bailey
O. Box 1391; 201 E. Center
Pocatello , ID 83204-1391
rcbcm. racinelaw. net
elocm. racinelaw. net
Hand Delivered
x U.S. Mail
Overnight Mail
FAX [phone]
E-mail
Anthony Yankel
29814 Lake Road
Bay Village , OH 44140
yankelcm.attbi.com
Hand Delivered
x U.S. Mail
Overnight Mail
FAX [phone]
E-mail
Peter J. Richardson
Richardson & O'Leary
515 N. 27th Street
O. Box 7218
Boise,. ID 83702
petercm. richa rd sona ndolearv. com
Hand Delivered
-L U.S. Mail
Overnight Mail
FAX [phone]
--x-E-mail
Dr. Don Reading
Ben Johnson Associates
6070 Hill Road
Boise , I D 83703
dread inqcm.m indsprinq .com
Hand Delivered
x U.S. Mail
Overnight Mail
FAX [phone]
E-mail
Lawrence A. Gollomp
Assistant General Counsel
United States Dept. of Energy
1000 Independence Avenue , SW
Washington , D.C. 20585
Lawrence. Gollompcm. hq .doe. qov
Hand Delivered
x U.S. Mail
Overnight Mail
FAX [phone]
E-mail
CERTIFICATE OF SERVICE , Page
Dennis Goins
Potomac Management Group
O. Box 30225
Alexandria, VA 22310-8552
dqoinsPMGcm.aol.com
Conley E. Ward
Givens, Pursley LLP
601 W. Bannock Street
O. Box 2720
Boise, ID 83701-2720
cewcm.qivenspu rsley .com
Dennis E. Peseau , Ph.D.
Utility Resources, Inc.
1500 Liberty Street S., Suite 250
Salem , OR 97302
dpeseaucm.excite.com
William M. Eddie
Advocates for the West
1320 W. Franklin Street
O. Box 1612
Boise , ID 83701
billeddiecm.rmci.net
Ken Miller
NW Energy Coalition
5400 W. Franklin , Suite G
Boise, ID 83705
Michael L. Kurtz
Kurt J. Boehm
Boehm , Kurtz & Lowry
36 East Seventh Street, Suite 1510
Cincinnati, Ohio 45202
mkurtzcm.bkllawfirm.com
kboehmcm.bkllawfirm.com
CERTIFICATE OF SERVICE , Page 2
Hand Delivered
x U.S. Mail
Overnight Mail
FAX [phone]
E-mail
Hand Delivered
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Overnight Mail
FAX [phone]
---L-E-mail
Hand Delivered
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Overnight Mail
FAX [phone]
E-mail
Hand Delivered
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Overnight Mail
FAX [phone]
---L-E-mail
Hand Delivered
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Overnight Mail
FAX
E-mail
Hand Delivered
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FAX [phone]
E-mail
BARTON L. KLINE