20080808IPC to ICIP 1-10.pdf

~IDA~POR~
An IDACORP Company
i~: 5ti.
BARTON L. KLINE
Senior Attorney
August 7, 2008
VIA HAND DELIVERY
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P.O. Box 83720
Boise, Idaho 83720-0074
Re: Case No. IPC-E-08-10
General Rate Case
Dear Ms. Jewell:
Enclosed for filing please find an original and three (3) copies each of Idaho Power
Company's Response to the First Production Request of The Industrial Customers of Idaho
Power and Idaho Power Company's Response to the Idaho Irrigation Pumpers
Association, Inc.'s First Data Requests to Idaho Power Company.
In addition, also enclosed are two (2) CDs, four copies of each. The CDs contain
the Company's responses to production/data requests in which electronic/excel files were
requested and also for ease of production of the information.
Upon receipt of this filing, I would appreciate it if you would return a stamped copy of
this letter for my file in the enclosed stamped, self-addressed envelope.
Very truly yours,
btJtt
Barton L. Kline
Senior Attorney for Idaho Power Company
BLK:csb
Enclosures
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, ID 83702
BARTON L. KLINE, ISB#1526
LISA D. NORDSTROM, ISB #5733
DONOVAN E. WALKER, ISB #5921
Idaho Power Company
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
bklinecæidahopower.com
Inordstromcæidahopower.com
dwalkercæidahopower .com
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 MAnER OF THE
APPLICATION OF IDAHO POWER
COMPANY FOR AUTHORITY TO
INCREASE ITS RATES AND
CHARGES FOR ELECTRIC
SERVICE.
) CASE NO. IPC-E-08-10
)
) IDAHO POWER COMPANY'S
) RESPONSE TO THE FIRST
) PRODUCTION REQUEST OF THE
) INDUSTRIAL CUSTOMERS OF IDAHO
) POWER
COMES NOW, Idaho Power Company ("Idaho Powet' or "the Company"), and in
response to the First Production Request of the Industrial Customers of Idaho Power
Company dated July 9,2008, herewith submits the following information:
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 1
REQUEST FOR PRODUCTION NO.1: Please provide a copy for each of the
three (3) cost of service studies presented in Mr. Tatum's Direct Testimony in electronic
format, CD-ROM with instructions on how to use them.
RESPONSE TO REQUEST FOR PRODUCTION NO.1: The requested material
is provided in electronic format on the enclosed CD.
This response to this Request was prepared by Timothy Tatum, Senior Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 2
REQUEST FOR PRODUCTION NO.2: Please provide Mr. Tatum's Exhibits No.
59 and Exhibits No. 68 in electronic format with instructions on how to use each.
RESPONSE TO REQUEST FOR PRODUCTION NO.2: The requested material
is provided in electronic format on the enclosed CD.
This response to this Request was prepared by Timothy Tatum, Senior Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 3
REQUEST FOR PRODUCTION NO.3: The Company's April 22, 2008 Marginal
Cost Analysis, provided in Mr. Tatum's workpapers states, "The 2008 test year gas
prices were used, adjusted for each of the years using the Utility Natural Gas Index from
the Global Insight 30-year US Economic Outlook, February 2008." Please provide the
2008 test year gas prices used in the 2008 Marginal Cost Analysis and show the
adjustment used for each year.
RESPONSE TO REQUEST FOR PRODUCTION NO.3: The 2008 test year gas
price used in the Company's April 22, 2008, Marginal Cost Analysis was $7.74 per
MMBTU. The gas prices for the years 2009-2012 were derived by applying the
following factors for each corresponding year:
Year Factor
2009 1.098
2010 1.039
2011 0.995
2012 0.985
For example, to derive the 2009 gas price used in the 2008 Marginal Cost Analysis, the
2008 test year gas price of $7.74 per MMBTU was multiplied by the 2009 factor of 1.098
resulting in a 2009 gas price of approximately $8.50 per MMBTU. For each of the years
2010-2012, the gas price was derived by multiplying the corresponding year's factor by
the gas price from the previous year. For example, the 2010 gas price was derived by
multiplying the 2009 gas price of $8.50 per MMBTU by the 2010 factor of 1.039. The
factors for 2009-2012 were developed according to the Utility Natural Gas Index from
the Global Insight 30-year US Economic Outlook, February 2008.
This response to this Request was prepared by Timothy Tatum, Senior Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 4
REQUEST FOR PRODUCTION NO.4: Ms. Nemnich on page 3 of her direct
testimony detailing the proposed rate design for industrial and commercial customers
states: "i gathered customer input on proposed rate design changes during a meeting
held on May 8, 2008, that included several of the Company's Large General Service
customers. A summary of this meeting is included later in my testimony." Please
provide the full details of this meeting including: participants, maters discussed
documents distributed or received, a full description of the topics discussed, and a
detailed explanation of how any information gained through this meeting influenced the
proposed rate design.
RESPONSE TO REQUEST FOR PRODUCTION NO.4: In order to gather
customer input on proposed time-of-use rates, and with the intent of finding a proposal
agreeable to our customers, Idaho Power held a meeting on May 8, 2008, for customers
taking service on Schedule 9 at the primary and transmission service levels. Attached
hereto is the participant list, a list of topics discussed, and copies of documents
distributed.
The discussion during this meeting was part of a larger body of information used
by the Company to determine the rates and rate design contained in my testimony.
This response to this Request was prepared by Darlene Nemnich, Senior Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 5
REQUEST FOR PRODUCTION NO.5: Please detail the allocation to schedule
19 customers of the transmission and distribution costs associated with the company's
combustion turbine generation facilities.
RESPONSE TO REQUEST FOR PRODUCTION NO.5: In the Company's
preferred class cost-of-service study, the "3CP/12CP Study," all costs that were
determined to be transmission-related were allocated to Schedule 19 according to the
associated 013 allocation factor listed on Exhibit No. 68, page 3. The methodology
used to derive the 013 allocation factor is described on pages 37-39 of Mr. Tatum's
testimony. Distribution-related costs were allocated to Schedule 19 on the basis of
either the class's non-coincident peak demand, the number of customers or were
directly assigned. The demand-related, customer-related, and direct assignment
allocation factors used to apportion distribution-related costs to Schedule 19 in the
3CP/12CP Study are listed on Exhibit No. 64, page 47, column G, lines 24-45. The
methodology used to derive each of the allocation factors listed on Exhibit No. 64 is
detailed in Mr. Tatum's workpapers.
This response to this Request was prepared by Timothy Tatum, Senior Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 6
REQUEST FOR PRODUCTION NO.6: Mr. Lamont Keen, on page 6, lines 11-
13 of his direct testimony states "we have experienced an increase in average annual
energy usage by residential customers in four or the last five years". Please provide the
average annual usage of electricity for each customer class for the previous five years.
RESPONSE TO REQUEST FOR PRODUCTION NO.6: Please see attached
table.
This response to this Request was prepared by John R. Gale, Vice President,
Regulatory Affairs, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 7
REQUEST FOR PRODUCTION NO.7: Ms. Smith's direct testimony includes
Exhibit 33 which details the various methodologies used to convert the 2007 actual date
to the 2008 test year data. Please provide a detailed accounting which compares the
2008 test year data with the actual 2008 data collected though July i, 2008 for any line
item identified in Exhibit 33 which utilizes the 3 year compounded, 5 year compounded,
or normalized methodologies.
RESPONSE TO REQUEST FOR PRODUCTION NO.7: This response wil be
made available as soon possible after 2nd Quarter Earnings Release.
This response to this Request was prepared by Lori Smith, Vice President of
Corporate Planning and Chief Risk Offcer, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 8
REQUEST FOR PRODUCTION NO.8: In arguing for the use of the 2008 test
year Mr. Gale refers to the Company's experience with the forecast component of the
PCA mechanism on page 15, lines 1-6 of his direct testimony. Please provide a
detailed analysis that compares the forecasted component of the PCA with the actual
data found for the years 2000-2007.
RESPONSE TO REQUEST FOR PRODUCTION NO.8: The deferral report
exhibits that were submitted with the Company's annual PCA filings for years 2000
through 2007 are attached. These exhibits provide the detailed analysis which
compares the forecasted component of the PCA with actual data from the PCA year.
Please note, the unreadable values shown in the column labeled "totals" for the IPC-E-
00-6 (year 2000) filing are row 24: $61,486,000, and row 25: $11,075,000.
This response to this Request was prepared by Celeste Schwendiman, Senior
Pricing & Regulatory Analyst, Idaho Power Company, in consultation with Barton L.
Kline, Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 9
REQUEST FOR PRODUCTION NO.9: Ms. Drake, on page 4, lines 2-7 refers to
the Company's Demand-Side Management 2007 Annual Report which covers all
demand response programs. Please provide this report along with any and all
documents, reports, studies, data, or analysis used in developing this report.
RESPONSE TO REQUEST FOR PRODUCTION NO.9: In response to a
production request, issued by the Industrial Customers of Idaho Power in Case No. IPC-
E-08-13, Idaho Power provided a copy of the Demand-Side Management 2007 Annual
Report. This report was filed with the Idaho Public Utilities Commission on April 14,
2008, and is also available at:
http://w.idahopower.com/aboutus/regulatorvinfo/reportPdf.asp?id=44&.pdf.
The documents, reports, studies, data, and analysis used in developing this report are
too voluminous to provide as part of a production request. The requested supporting
materials for the Demand-Side Management 2007 Annual Report wil be made available
for examination in the discovery room at the Idaho Power Headquarters, 1221 West
Idaho Street, Boise, Idaho. Please contact Doug Jones (388-2615) or Camila Victoria
(388-5821) to make an appointment to review this information.
This response to this Request was prepared by Theresa Drake, Manager,
Customer Relations and Energy Efficiency, Idaho Power Company, in consultation with
Barton L. Kline, Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 10
REQUEST FOR PRODUCITON NO 10: Please provide any and all documents,
reports, studies, data, or analysis used in the all aspects of the Company's investigation
of the Virtual Peaker Program.
RESPONSE TO REQUEST FOR PRODUCTION NO. 10: In response to this
Request, attached are copies of the following reports and analysis used in the
Company's investigation of the Virtual Peaker Program:
· Idaho Power's Virtual Peaking Program status report filed with the Idaho
Public Utilities Commission on June 1,2007. This report summarizes the
research the Company had done prior to June 1, 2007, with regards to a
Virtual Peaker program.
. Idaho Power's Virtual Peaker Program update filed with the Idaho Public
Utilities Commission on April 4, 2008. This report updates the first report,
details the Company's findings from the engineering analyses and
requests that the Commission schedule a workshop for the purpose of
receiving feedback from interested parties.
In addition, the Company has a Virtual Peaker Levelized Cost Analysis updated on April
8, 2008, and a copy of the confidential reports prepared by POWER Engineers that
detail the interconnection cost analysis for each of our five customers that committed to
an on-site visit. Idaho Power takes its obligation to protect the privacy of its customer's
information seriously. Idaho Power and Staff have entered into a protective agreement
in this case. Idaho Power is willng to make the above-described customer-specific
reports and the updated Virtual Peaker Levelized Cost Analysis available for the ICIP's
review at the offces of Idaho Power if the ICIP enters into the protective agreement.
Please contact Doug Jones (388-2615) or Camila Victoria (388-5821) to make an
appointment to review this information.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 11
This response to this Request. was prepared by Courtney Waites, Pricing
Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney,
. Idaho Power Company.
/! Jy.
DATED at Boise, Idaho, this 3: day of August 2008.
ß*~
BARTON L. KLINE
Attorney for Idaho Power Company
LISA D. NORDSTROM
Attorney for Idaho Power Company
DONOVAN E. WALKER
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - .12
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 7th day of August 2008 I served a true and
correct copy of the within and foregoing document upon the following named parties by
the method indicated below, and addressed to the following:
Commission Staff
Weldon B. Stutzman
Deputy Attorney General
Idaho Public Utilities Commission
472 West Washington
P.O. Box 83720
Boise, Idaho 83720-0074
Neil Price
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington (83702)
P.O. Box 83720
Boise, Idaho 83720-0074
Industrial Customers of Idaho Power
Peter J. Richardson, Esq.
RICHARDSON & O'LEARY PLLC
515 North 2th Street
P.O. Box 7218
Boise, Idaho 83702
Dr. Don Reading
Ben Johnson Associates
6070 Hil Road
Boise, Idaho 83703
Idaho Irrigation Pumpers
Association, Inc.
Randall C. Budge
Eric L. Olsen
RACINE, OLSON, NYE, BUDGE &
BAILEY, CHARTERED
P.O. Box 1391
201 East Center
Pocatello, Idaho 83204-1391
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FAX
-X Email Weldon.stutzmantãpuc.idaho.gov
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-X Email Neil.pricetãpuc.idaho.gov
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-- Email petercærichardsonandolearv.com
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L Email dreadingcæmindspring.com
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L Email rcbtãracinelaw.net
elocæracinelaw. net
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 13
Anthony Yankel
Yankel & Associates, Inc.
29814 Lake Road
Bay Vilage, Ohio 44140
Kroger Co. I Fred Meyer and Smiths
Michael L. Kurtz
Kurt J. Boehm
BOEHM, KURTZ & LOWRY
36 East Seventh Street, Suite 1510
Cincinnati, Ohio 45202
The Kroger Co.
Attn: Corporate Energy Manager (G09)
1014 Vine Street
Cincinnati, Ohio 45202
Kevin Higgins
Energy Strategies, LLC
Parks ide Towers
215 South State Street, Suite 200
Salt Lake City, Utah 84111
Micron Technology
Conley Ward
Michael C. Creamer
GIVENS PURSLEY, LLP
601 West Bannock Street
P.O. Box 2720
Boise, Idaho 83701-2720
Dennis E. Peseau, Ph.D.
Utility Resources, Inc.
1500 Liberty Street SE, Suite 250
Salem, Oregon 97302
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L Email tonycæyankel.net
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-- Email mkurtzcæBKLlawfrm.com
kboehmcæBKLlawfirm.com
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Email
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~ Email khigginscæenergystrat.com
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-- Email cewtãgivenspursley.com
mcc(givenspursley.com
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-X Email dpeseaucæexcite.com
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 14
Department of Energy
Lot R. Cooke
Arthur Perry Bruder
Offce of the General Counsel
United States Department of Energy
1000 Independence Avenue SW
Washington, DC 20585
Routing Symbol GC-76
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Arthur. Brudertãhg .doe.gov
Dwight Etheridge
Exeter Associates
5565 Sterrett Place, Suite 310
Columbia, MD 21044
Hand Delivered
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-- Email detheridgecæexeterassociates.com
Community Action Partnership
Association Of Idaho
Brad M. Purdy
Attorney at Law
2019 North 1th Street
Boise, Idaho 83702
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-- Email bmpurdycæhotmail.com
\
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST
PRODUCTION REQUEST OF THE INDUSTRIAL CUSTOMERS OF IDAHO POWER - 15
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-08-10
IDAHO POWER COMPANY
RESPONSE TO REQUEST NO. 4
Rate Schedule 09P Customer Meeting
May 8,2008
Attendee List:
JoAnne Smith, Facilities Manager, T-Mobile
Roger Dean, Director of Building Services, St Luke's
Jeremy Malone, Director of Property Management, Oppenhiemer Development
(Wells Fargo)
Michael Wilson, Accountant, and John Richert United Water of Idaho
Kevin Higgins, Consultant, Energy Strategies, representing Kroger (Fred
Meyers)
Dave Schunke, Idaho Public Utilities Commission
Keith Hessing, Idaho Public Utilities Commission
Darlene Nemnich, Idaho Power Company
Maggie Brilz, Idaho Power Company
Tim Tatum, Idaho Power Company
Greg Said, Idaho Power Company
Wilma Walp, Idaho Power Company
Steve Floyd, Idaho Power Company
Rate Schedule 09P Customer Meeting
May 8, 2008
Agenda:
i) Background
· 2004-curent Rate 19 TOU rates,
. IPUC Order 30508 Feb '08,
2) Review of rate design objectives
· Establish prices which primarily reflect the cost of services produced, this wil give customers
more correct price signals
. Recover revenue for that customer class
· Design rate strctues that do not encourage customers to move from one rate class to the next
· But when a customer does move naturally, make the change a smooth transition.
· Provide opportity for customers to shift and save.
What design objectives are customers interested in?
We are asking for input on general rate structures not necessarily rate levels.
3) Provide brief overview of research fidings
. Curent Idaho Power rate 09 and 19 (hand out schedules?)
. Other utilties rate strctues (handout, explain carefully, Higgins)
4) Review proposed time-of-use rate strcture
. Handout bar char discuss seasonal and hourly rate components - TOU
Is it valuable that the structure be the same between 09 and 19?
Same time period? Or do you prefer two (higher 7 am-1 Ipm) or three (add 1pm-9pm)
If you were on a TOU rate would you tr to shift your usage?
· How much ofa diffrential would make you shift?
. If we were to add more cost during on-peak times, would you like more on the demand or kWh
component?
What changes would you have make to your operations in order to shift?
Should the rates be voluntary or mandatory?
. If voluntary, would you participate?
For those of you who have facilities in other utilties, do you have a favorite rate strctue?
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BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-08-10
IDAHO POWER COMPANY
RESPONSE TO REQUEST NO.6
Idaho Power Company
Average Annual Use per Customer
Based on Actual Usages
2007 2006 2005 2004 2003 2002
Annual Avg Annual Ava AnnualAvg Annual Ava Annual Ava Annual Ava
Customer kWh per kWh per kWh per kWh per kWh per kWh per
Class Customer Customer Customer Customer Customer Customer
Residential 13,066 13,054 12,603 12,550 12.528 12,971
Commercial 66,708 66,705 65,734 66,256 66,564 67,430
Industrial 18,155,094 17,017,044 17,517,738 18,373,710 19,102,124 18,614,061
Agricultural 122,352 104,081 94,110 120,691 132,615 132,971
Lighting 19,915 21,918 24,337 26,492 30,336 31,878
Totals 27,864 27,234 26,768 27,712 28,274 28,822
Special Contracts 361,414,714 360,331,500 356,070,471 350,509,224 338,804,122 305,884,357
Total Idaho 30,233 29,660 29,254 30,252 30,810 31,505
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-08-10
IDAHO POWER COMPANY
RESPONSE TO REQUEST NO.8
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pca2001rnlled 3/19101 10:35 AM
I A I B I M
1 TP:.r Cost Adjustnt Calculations. !
1¡r: 1~gpõüiruMãr2õõ1--.--;._n. .'-' :----"Fëi-( C2. ¡ _L___...._~_4 PCA Revnue I!
5 Nonnaliz Finn Load ! -¡--
¡6 PCA Component Rate ,
¿ Revenue at 85%
8
9 Lod Change Adjustment
10 Actal Finn Lo - Adius
11 Nonnarized Finn Loa
12 Load Change
13 Expense Adustmnt (~ 16.84)
14
15 Actual Non-QF PCA
16 urcase Water17 pense Adiuslment $18 uel Exse $19 on-Firm Purcase $20 urplus Sales $
21 F liC 2'nd Blk Engy-Cmcty Price OnIÝ$22 tal Non-OF $
23
24 ASE25 F el Exnse 1$ ,
26 IN on-inn Purcase i$ I27 S rplus Sales ~$ I
28 IF I.C 2'nd elk Engy-Cmdty Pric Onlý$
29 NElt90% Items i$30 T31 C anae Fro Base 1$
32
33 S aring Percriae '
34 Id aho Allocation :35 i
36 N n-QF Deferrl :$37 !
38 A :lal OF (Includes Meriian Amort) 1$39 i40 B seOF 1$41 !
42 C ange From Base i$43 !44 81 arlng Percentage i45 Id ho Allocion !
46
47 Q Deferrl
48
49 T tal Defel
50
51
52 Pr ncipal Balances
53
54 BE ginning Balance _.55 -.
56 IAi ount Deferred ._-- . $ -+ 23,996,229.18
57
58 E~ cling .Balance
59
60 lii rest Balances -.----.--,-.--¡---------_. ---~.-----61 ' 1 .
62 At ::al thru Prior Month :$ .-l_...---- --- 0.00-63 --.--------.------ ---
"ã Më ñi~iñiereie..-----_===~~--.. .=-~=---~65 ' ;
66 Monlhii Interet Incl(Exp)---..--$.~~..t=~~ 758,9-:67 .
68 Int ret Acced to'ijãt---. 1$ ; 758,949.3669 ---------~--
70 Ba anëèiñAeëOunt 182.323 -.------.$---., 24,755,178.54¡. ..- _.-.~_. ..... ._-_.. .._----- .__.__.-71
Mw
Mw
Mwh
i
i$
:$
$
1,162,223
1.832
1,809,813.66
1,194,605
1,162,223
32,382
(984,550.60)
0.00
(984,550.60)
8,651,746.29
5,465,268.94
21,065,292.33
(7,295.0)
33,463,461.96
5,051,000.00
642,000.00
(2,781,000.00)
(769,197.02)
2,142,802.98
31,320,658.98
I
I
90%
85%
iT
T
23,960,304.12
3,631,242.31
I
!
¡
i
1,459,785.00
2,171,457.31
i
I
i
100%
85%
1,845,738.71
23,996,229.18
i
159,234,648.64
"-=-=~-$ -=~~.23,996,22~:.
".
Exhibit 3
Case No. IPC-E..1-11
Gregory W. Said
Page 1 of 1
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Case No.IPC-E-05-_
C. Schwendiman, IPCo
Page 1 of 1
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Jnne 1,2007
Ms. Jean D. Jewell, Secreta
Idaho Public Utities Commsion
472 Wes Wasngtn Street
P. O. Box 83720
Boise, il 83720-0074
RE: Vir Peaer Program
Ca No. IPC~E-06-09
Dea Ms. Jewell:
c.
Enclosed pleas fid eight copies of Idaho Power's Virt Peakg Progr statu reort. Ths
report is fied in compliance with the Idaho Public Utilities Commisson Order No. 30201.
The Company previewed the inormaton included in th report with Commsion Sta and the
Indus Customers of Idaho Powe on May 15th, 2007. As stted in th report, the Company will
submit a detaed report of its fidigs to the Commssion afr the completon of its "Engieerg
Anysis Pilot Progr" and updated fiancial analysis.
If y'ou have any quesons regarg ths fi, pleae do not hestae to conta me.~..,~~~s
Pricin Anyst
CW:cw
ce: Ric Gae
Magge Brilz
(
Prcing & Regulatory Servces
Voice: 208-388-5612
Fax: [phone]
cwaies(gdaopower.com
P.O. Box 70 (83707)
1221 W.ldahoSt.
Boise, 1083702
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IDA""POR8
An IDACORP company
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VIRTUAL PEAKER PROGRAM
Background
Over the past ten years, Idaho Power has periodically investigated the possibilty of
implementing a distributed generation program as an alternative resource to help meet
peak demands. In the fall of 2006, the Company once again began investigating thepotential for a program. Shortly after, the Industrial Customers of Idaho Power and the
Idaho Public Utilties Commission (IPUC) expressed an increased interest in this type of
program and on December 15, 2006. the IPUC issued Order No. 30201, which directed
Idaho Power to "investigate and submit a report for the implementation of a 'virtual
peaking plant' program based upon the use of existing emergency generator resources
in the Company's seivice territory." This report is filed in compliance with Order No.30201. .
As part of our research, the Company reviewed virtual peaking programs other utilties
have successfully operated and focused on two designs: The Dispatchable Standby
Generation program conducted by Portland General Electric Company (PGE) and
Madison Gas and Electric's (MGE) Backup Generation Service. The primary difference
between the two programs is in regards to the ownership of the generator: MGE owns
the generator located on the customets premises whereas PGE's customers own their
generator. Also, MGE customers pay a monthly service charge based on their
maximum annual kilowatt demand for electricity. Idaho Power chose PGE's program
model to use as a basis for our program development.
Program Description
A dispatchable standby generation program would allow the Company to use
nonresidential customers' standby generators for up to 400 hours a year to meet system
peak power demands. Customers' generators would operate in parallel with Idaho
Power's system while also being available to back up their facilty when needed. The
Company's design wil be such that during an outage situation, the customets
generator(s) wil automatically start and provide backup power to the customer for as
long as needed as originally intended by the customer. During times when customers'
generators can be beneficial to the Company's system, the generators wil be started
remotely by the Company's dispatch center.
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The following are the responsibilties of the customer and the Company under the
'\ proposed program design:
Customer Responsibilites: Customers wil be responsible for purchasing
the generator(s) and providing the site for generator installation. In
addition, customers will grant the Company access to their generation
such that the Company can control operation of the generator(s) remotely
in paralfel with the Company's distnbution system from the Company's
dispatch center for up to 400 hours per year. Customers may operate the
generator(s) at their sites as needed for emergency back-up power.
Company Responsibilities: The Company wil conduct an analysis of the
customer's generator project and develop a comprehensive cost estimate.
The Company wil be responsible for providing interconnection
engineenng, facilties, and installation and any other equipment necessary
for participation in the program. The Company wil pay for and own all
communications and metering equipment.
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In addition, the Company wil be responsible for routine maintenance of the generator(s)
including overhauls over the term of the service agreement. The Company wil also pay
for all fuel used to operate the customets generator(s) throughout the term of the
service agreement. The Company wil perform monthly full-load testing of the
customer's generator(s) and control system and testing of the Company's dispatch
control and interconnection facilties. All energy consumed by the customer while
participating in the program wil be biled at standard tariff rates.
The following is a partial listing of the infrastructure that would need to be in place for
such a program to run:
· Utility Paralleling Power System (UPPS) - The UPPS wil ensure that
the customer is provided with a continuous supply of electric power by,
almost instantaneously, switching from the Company's power supply to
the back-up generator's power supply in the event of a power failure.
· Metenng - For an existing generator to be retrofitted, an additional
time-based meter would be required. New generators would require two
time-based meters be installed. The time-based meters would ensure that
whether customers are drawing energy from the Company's system or
from the back-up generator, their usage is tracked and biled under the
standard service schedule.
· Communication Node Netwòrk - For communication between the
customer's system and the Company's system, a frame relay based
network would be installed in order to provide a secure network.
· Energy Management System (EMS) - The EMS would need to be
programmed to accept the data from the UPPS.
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Feasibilty Analysis
In our feasibilty analysis, the Company looked at the various costs involved in the
interconnection of a back-up generator as well as the resulting operations and
main tenance costs which wil be covered by the Company. Both initial generator
installations and existing retrofits were considered. The initial analysis indicated there is
enou gh potential benefit associated with the program to continue pursuing its
investigation.
Pilot Program
The feasibilty analysis concluded that Idaho Power would need to make an investment
in in frastructure of approximately $1 millon in order to integrate customer-owned
generators into our system. Because of the investment size and the potential
complexit of the interconnection of some generators, the Company determined it was
necessary to do an ¡n-depth analysis of the interconnection costs, targeting generators
of different sizes, ages, and locations. This thorough analysis would provide more
detailed costs of interconnection and a more accurate determination of the program's
potential viabilty.
In order to complete the in-depth cost analysis, Idaho Power met with numerous
customers, as well as representatives of the Industrial Customers of Idaho Power, to
describe the potential program and solicit participation in an "Engineering Analysis Pilot
Program". Through this process, Idaho Power hopes to identif four to six customers
who are willng to work with Company personnel in the development of this initial cost
estimate for their. specific facilties. The Company is targeting customers whose existing
generators vary in size and customers who do not currently have back-up generators
. but would consider installng one if a "virtual peaker" program were offered.
The Company plans to conduct the interconnection cost estimate analyses over the
next three months. Once detailed interconnection cost information is available, the
Company wil update its financial analysis to determine if a "virtual peaket' program is
economically viable ånd submit a detailed report of its finding to the Commission.
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~IDA..PO~
An JOACORP Company
Barton L. Kline
Senior Attorney
April 4, 2008
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
. P. O. Box 83720
Boise, Idaho 83720M0074
Re: Virtual Peaker Program Update
Dear Ms. Jewell:
On June 1 , 2007, Idaho Power filed a report with the Commission in compliance with
Order No. 30201 (Case No. IPC-E-06-09) detailng the Company's investigation into the
implementation of a virtual peaking plant program. In the June 1 report, the Company
indicated it would submit to the Commission a detailed report of its findings following
additional investigation into the costs of interconnecting customer-owned backMup
generation into its system. Attached is the Company's updated report.
As detailed in the updated report, the Company has determined that it Is economic
to operate customer-owned diesel generators during short periods of high demand.
However, the Company has received several inquiries asking about the environmental
ramifications associated with operating diesel generators as a part of the 'virtual peaker'
program. In order to allow interested parties the opportunity to provide input regarding the
implementation of a diesel generator peaking program, Idaho Power believes convening a
workshop is the logical next step. In the report, the Company respectfully requests that the
Commission schedule a workshop for the purpose of receiving feedback from interested
parties.
If you have any questions, please feel free to contact either me or Maggie Bnlz at
388-2848.
..
Barton L. Kline
BLK:sh
Enclosures
P.O. Box 70 (83107
1221 W.ldaho St
Bolse, 10 B3702
ØSIDA~PO~
(M IDACORP coV
April 4. 2008
VIRTUAL PEAKER PROGRA
UPDATE
Background
(
Over the past ten years. Idaho Power has periodically investigate the possibilit of
implementing a distrbuted generation program as an alternative resource to help meet
peak demands. In the fall of 2006, the Company once again began invesgating the
potential for a program. Shorty after, the Industrial Customers of Idaho Power (leIP)
and the Idaho Public Utilities Commission (IPUC) expressed an increased interest in
this tye of program and on Decmber 15, 2006, the IPUC issued Order No. 30201.
which directed Idaho Power to "investgate and submit a report for the implementation of
a 'virtal peaking planf program based upon the use of existing emergency generator
resources in the Company's service territory." This report was filed wih the
Commission on June 1, 2007 and is included as Attachment 1. The June 1 report
details the Company's investigative activities, the potential design of the program, the
results of the Company's initial feasibilty analysis, and the Company's plans to conduct
an interconnection cost analysis through a pilot program.
At the time the report was filed, the Company planned to conduct the interconnecion
cost estimate analyses during the summer of 2007. With this detailed interconnecon
cost information, the Company would update its financial anaJysis to determine if a
virtal peaker program is ecnomically viable.
Program Update
Following the filing of the June 1 report, Idaho Power's Delivery Service
Representatives (DSRs) contacted those customers whom they knew had existing
generation, thos customers who had expresed an interest in adding generation, and
those customers whom they thought might have generation. Based on the leads of the
DSRs. the Company held numerous customer meetings and conference calls detailng
the potential program. Additionally, in an efrt to gain more awareness of the program,
the Company met with representatives of the ICIP and requested the IClP forward the
names of any customers who might be interested in participating. The Company also
described the program during meetings held with industrial customers in June, 2007 to
explain the recently filed general rate case and the energy effciency opportunities
offered by the Company. Through this proce, Idaho Power reeived the names of two
(
( customers from the ICIP and talked with a total of fort-five customers about the'
potential for a virtual peaker program. Of those customers, twelve expressed aninterest in having more in-depth talks and ultimately five customers committd to
allowing the Company to perform an on-site intercnnection cost analysis.
In an attempt to be more economical and timely, the Company engaged the services of
a consultant to perform the interconnection cost analyses of the five customers. Idaho
Power issued a Request for Proposal (RFP). in order to obtain the most competitive
price for the cost analyses. A negotiated contract was finalized with Power Engineers
on August 24, 2007 and the on-site work was conducted between September 18, 2007
and September 24, 2007. The cost data associated with the on-site analysis was
provided to the Company on November 14, 2007. The Company took this data and
updated its initial financial analysis to incorprate the detailed intercnnection cost dat.
Based on the comparatively low capital cost per kilowatt to intercnnec customers'
back-up generators and the relatively high dispatch cost per kilowatt-hour, the
Company's analysis indicated it is economic to operate diesel generators during short
periods of high demand. With this conclusion, the Company began investigating air
quality and permiting Issues.
~.
To better understand the environmental ramifications of running diesel generators, the
Company began it investigation into air quality and permitting issues by holding
discussions wih the Deparnent of Environmental Quality (CEQ). Through these
discussions it was determined that partcipation in the virtual peaker program would
require customers. with existing generators to modif their current permits because they
would no longer be using the generators exclusively for emergency purposes. To
modify their permit, the Company's research indicated customers would be required to
submit an application along with an air quality analysis based on total emissions on the
customers' premises. Costs of the permit alone are a minimum $1,000 plus an
additional amount based on the amount of the customets emissions (estimated to be
about $5,000).
Following the talks wih the DEQ, the Company solicited input from the environmental
community. A few concerns were raised during these discussions including the impact
of the generators on air quality, the new ozone requirements expected to be issued by
the Environmental Protection Agency (EPA), and the current carbon concerns. If a
virtual peaker program was approved and implemented, the Company would most likely
be dispatching customers' generators, almost all of which utilze diesel fuel, at times of
peak sysem demand, which fs most often on hot. summer afternoons - times when air
quality may already be troubled. Based on the Company's research, a diesel generator
emits approximately fift times more nitrous oxide and approximately five to ten times
more carbon monoxide than a natural gas fired simple cycle combustion turbine.
Biodiesel and natural gas conversions could be options that might reduce air quality
concerns, however it is not known if exlstlng customer-owned generators could switch
to this fueL.
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Conclusion of Findings and Next Steps
The Company's actions described above demonstrate a serious commitment to
pursuing a virtual peaker program in the Company's servce territory. While its current
program design may prove to be cost effective, environmental ramifications may exist if
the program is implemented. It is because of these impacts that Idaho Power believes
the next logical step is to hold a workshop soliciting customer input regarding the
implementation of a virtual peaker program in the Company's service territory. If the
Commission agrees, Idaho Power respectfully requests the Commission schedule a
workshop for the purpose of receiving feedback from interested parties. Based on the
results of the workshop, Idaho Power would then submit to the Commission its
recommended course of action.
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ATTACHMENT 1
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*SIDA~POR4Ð
An IDACOl COmpany
VIRTUAL PEAKER PROGRAM
Background
Over the past ten years, Idaho Power has periodically investigated the possibilty of
implementing a distnbued generation program as an alternative resource to help meet
peak demands. In the fall of 2006. the Company once again began investigating the
potential for a program. Shortly after, the Industrial Customers of Idaho Power and the
Idaho Public Utilities Commission (IPUC) expressed an increased interest in this type of
program and on December 15, 2006, the IPUC issued Order No. 30201. which directed
Idaho Power to "investigate and submit a report for the implementation of a 'vIrtual
peaking plant' program based upon the use of existing emergency generator resources
In the Company's service territory." This report Is filed in compliance with Order No.30201. ..
As part of our research, the Company reviewed virtual peaking programs other utiltles
have successfully operated and focused on two designs: The Dlspatchable Standby
Generation program conducted by Portland General Electric Company (PGE) and
Madison Gas and Electric's (MGi=) Backup Generation ServIce. The primary difference
between the two programs is in regards to the ownership of the generator: MGE owns
the generator located on the customets premises whereas PGE's customers own theIr
. generator. Also, MGE customers pay a monthly service charge based on their
maximum annual kilowatt demand for electricity. Idaho Power chose PGE's program
model to use as a basis for our program development
Program Description
A dispatchable standby generation program would allow the Company to use
nonreidential customers' standby generators for up to 400 hours a year to meet system
peak power demands. Customers' generators would operate in parallel with Idaho
Power's system whiJe also being available to back up their facility when needed. The
Company's design will be such that during an outage situation, the customets
generator(s) wil automatically start and provide backup power to the customer for as
long as needed as originally intended by the customer. During times when customers'
generators can be beneficial to the Company's system, the generators will be startedremotely by the Company's dispatch center.
"
(.The following are the responsibilties of the customer and the Company under the
proposed program design:
Customer Responsibilities: Customers wil be responsible for purchasing
the generator(s) and providing the site for generator installation. In
addition, customers wil grant the Company access to their generation
such that the Company can control operation of the generator(s) remotely
in parallel with the Company's distnbution system from the Company's
dispatch center for up to 400 hours per year. Customers may operate the
generator(s) at their sites as needed for emergency back~up powr.
Company Responsibilties: The Company wil conduct an analysis of the
customer's generator project and develop a comprehensive cost estimate.
The Company wil be responsible for providing interconnection
engineering. facilities, .and installation and any other equipment necessary
for participation in the program. The Company will pay for and own all
communications and metering equipment.
In addition, the Company wil be responsible for routine maintenance of the generator(s)
including overhauls over the term of the service agreement. The Company wil also pay
for all fuel used to operate the customer's generator(s) throughout the term of the
service agreement. The Company wil perform monthly full-load testing of the
customer's generator(s) and control system and testing of the Company's dispatch
( control and interconnection facilities. All energy consumed by the customer while
". partcipating in the program will be biled at standard tariff rates.
The following is a partal listing of the infrastructure that would need to be in place for
such a program to run:
· utlity Paralleling Power System (UPPS) - The UPPS wil ensure that
the customer is provided with a continuous supply of electic power. by,
almost instantaneously, switching from the Company's power ~upply to
the back-up generator's power supply in the event of a power failure.
· Metering - For an existing generator to be retrofitted, an additional
time-based meter would be required. New generators would require two
time-based meters be installed. The time-based meters would ensure that
whether customers are drawing energy from the Company's system or
from the back-up generator, their usage is tracked and biled under the
standard service schedule.
· Communication Node Network - For communication between the
customer's system and the Company's system, a frme relay based
network would be installed in order to provide a secure network.
· Energ Management System (EMS) - The EMS would need to be
programmed to accept the data from the UPPS.
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FeasibUitv Analysis
In our feasibilty analysis, the 0 Company looked at the various costs involved in the
interconnection of a back-up generator as well as the resulting operations and
maintenance costs which wil be covered by the Company. Both initial generator
installations and existing retrofrts were considered. The initial analysis indicated there is
enough potential benefit associated with the program to continue pursuing its
investigation.
Pilot Program
The feasibilty analysis concluded that Idaho Power would need to make an investment
in infrastructure of approximately $1 milion in order to integrate customer~owned
generators into. our system. Because of the Investmnt size and the potential
complexity of the interconnecton of some generators, the Company determined it was
necessary to do an in-depth analysis of the interconnection costs, targeting generators
of different sizes. ages, and locations. This thorough analysis would provide more
detailed costs of interconnection and a more accurate determination of the program's
potential viability. .
In order to complete the in-depth cost analysis, Idaho Power met wlth numerous
customers, as well as representatives of the Industral Customers of Idaho Power, to
describe the potential program and solicit participation in an ~Engineering Analysis Pilot
Program". Through this process, Idaho Power hopes to identify four to six customers
who are willng to work with Company personnel in the development of this initial cost
estimate for their specific facilties. The Company is targeting customers whose existing
generators vary in size and customers who do not currently have back-up generators
but Would consider installng one if a "virtal peaker" program were offered.
The Company plans to conduct the interconnection cost estimate analyses over the
next three months. Once detailed interconnection cost information is available, the
Company wil update it financial analysis to determine if a ."virtal peaker" program is
economically viable and submit a detailed report of its finding to the Commission.