20211021IPC to Staff 1-14.pdf

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DONOVAN WALKER
Lead Counsel
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October 21,2021
VIA ELECTRONIC FILING
Jan Noriyuki, Secretary
ldaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg 8,
Suite 201-A(83714)
PO Box 83720
Boise, ldaho 83720-007 4
Re Case No. IPC-E-21-25
ln the Matter of the Application of ldaho Power Company's Petition for
Approval of a Customer Surcharge and Modified Line Route Configuration
for Construction of a New 138 lry Transmission Line in the Wood River
Valley
Dear Ms. Noriyuki
Enclosed for electronic filing, please find ldaho Power Company's Response to the
First Production Request of the Commission Staff in the above matter. Please feelfree to
contact me directly with any questions you might have about this filing.
Very truly yours,
Donovan E. Walker
DONOVAN E. WALKER (lSB No. 5921)
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: (208) 388€936
dwalker@ idahopower.com
Attorney for ldaho Power Company
IN THE MATTER OF IDAHO PO\A/ER
COMPANY'S PETITION
FOR APPROVAL OF A CUSTOMER
SURCHARGE AND MODIFIED LINE
ROUTE CONFIGURATION FOR
CONSTRUCTION OF THE NEW 138 I(/
TRANSMISSION LINE IN THE WOOD
RIVER VALEY
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
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CASE NO. IPC-E-21-25
IDAHO POWER COMPANY'S
RESPONSE TO THE FIRST
PRODUCTION REQUEST OF
THE COMMISSION STAFF
COMES NOW, ldaho Power Company ("ldaho Powef or "Company'), and in
response to the First Production Request of the Commission Staff to ldaho Power
Company dated September 30,2021, herewith submits the following information:
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF- 1
REQUEST NO. 1: lf the modified line route and surcharge are approved, please
explain in detail how expenses and surcharge revenue willbe tracked and reported to the
Commission.
RESPONSE TO REQUEST NO. 1: Accounting for the expenses and surcharge
revenue willfollow the FERC Uniform System of Accounts. lncremental capital costs will
be recorded in FERC Account 101, Utility Plant in Service and the appropriate FERC plant
accounts. Depreciation expense will be recorded in FERC Account 403 Depreciation
Expense and FERC Account 108 Accumulated Depreciation. Operations & Maintenance
(O&M) expenses will be recorded within the following utility operating expense accounts:
FERC Accounts 56X and 57X for transmission O&M, FERC Accounts 58X and 59X for
distribution O&M and FERC Account 92X for administrative and general O&M. Surcharge
revenue will be recorded in FERC Account 400 General Business Revenue. These
surcharge revenues will be tracked through a separate billing code in our customer billing
system.
Once the surcharge is implemented, ldaho Power will track the unrecovered
balance of the actual incremental costs. The Company proposes providing annual status
reports to the Commission as supplementalfitings in this case.
The response to this Request is sponsored byAubrae Sloan, Accounting Manager,
ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 2
REQUEST NO. 2: lf the modified line route and surcharge are approved, please
provide the following information regarding operation and maintenance ('O&M') of the
modified line:
a. How will O&M costs be paid for?
b. How will the general body of rate payers be held harmless for the incremental
maintenance costs incurred by undergrounding of the line?
c. Please describe expected annual O&M costs for the overhead portion of the
modified line.
d. Please describe expected annual O&M costs for the underground portion of the
modified line.
RESPONSE TO REQUEST NO.2: ldaho Power has not added any incremental
O&M cost attributable to the undergrounding of the Iine to the surcharge amount paid by
the Coun$. The Company does not believe the incremental O&M cost to be material.
ln the Company's original filing, Case No. IPC-E-16-28, the Company worked in
consultation with Power Engineers to estimate operation and maintenance costs
associated with Underground Transmission and Overhead Transmission for the Ketchum
Substation to Elkhorn Road transmission approved to be undergrounded in the
CPCN. For that approximately 2-mile distance, the annual levelized operations and
maintenance costs, expressed in 2016 dollars, for Underground Transmission and
Overhead Transmission were estimated at $26,558 and $13,124, respectively. Based on
the rough nature of the estimating prooess, immateriality of the difference, and shorter
distance of the Owl Rock Road extension (1.4 miles), the Company determined not to
assess the County an additional O&M charge when it developed its surcharge
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 3
methodology.
The primary contributors to additional annual cost for routine underground
transmission inspection include 1) partiat discharge testing every five years to inspect
cable splices and 2) semi-annual inspection of the entire system including rigorous vault
and appurtenances inspection. Both services would likely be contracted services.
The response to this Request is sponsored by Eric Hackett, Projects and Design
Senior Manager, ldaho Power.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF -4
REQUEST NO. 3: Please provide the expected useful Iives and the annualized
revenue requirement for the following:
a. The incremental 't .4 miles of transmission line that will be undergrounded.
b. The 8 miles of distribution line from the Wood River Substation to Owl Rock Road
that will be undergrounded.
c. The overhead transmission line included in the CPCN that is being replaced by the
undergrounded transmission !ine
d. The overhead distribution line included in the CPCN that is being replaced by the
undergrounded distribution line.
RESPONSE TO REQUEST NO.3: Because ldaho Power's application requests
collecting the incremental costs through a customer surcharge, the Company calculated
the revenue requirement on the incremental costs based on a surcharge financing model
using a 2}-year surcharge period and depreciable life, rather than a traditional revenue
requirement model. As a result, the Company does not have a revenue requirement by
line segment. Rather, the Company calculated the rate base and revenue requirement
impacts of the incremental costs using a 2O-year depreciable life to ensure that the
surcharge revenue fully covers the revenue requirement so that ldaho Powe/s broader
retail customer base is not negatively impacted.
ldaho Power calculated the incremental costs of the additiona! Ow! Rock Road
Route burials as the difference between (1) the total estimated project cost for the CPCN
Route and (2) the total actual project cost of the Owl Rock Road Route. The difference
between these two total project costs represents the incremental cost of the Owl Rock
Road Route to be financed through the surcharge. The actual cost for the Owl Rock Road
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 5
Route will be determined after completion of the project. By contrast, the cost of the CPCN
Route must be estimated, since the CPCN Route will not actually be constructed. ldaho
Power plans to calculate the estimated cost of the CPCN Route when it receives finalpre-
construction pricing information for the Ow! Rock Road Route. This most current pricing
information for the Owl Rock Road Route would provide the most accurate data for
estimating the cost of the CPCN Route, since both routes will include both overhead and
underground transmission construction. The Company has not developed separate
revenue requirement calculations for the sub-parts of the total project listed in c-d above.
The attachment to this request provides a calculation of the 2O-year levelized revenue
requirement based on the surcharge financing modelfor both underground transmission
and underground distribution, as well as a high-level "loan amortization" model showing
the recovery of the incremental costs over the 20-year surcharge period.
a. See above.
b. See above.
c. See above.
d. See above.
The response to this Request is sponsored by Mark Annis, Regulatory Consultant,
ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 6
REQUEST NO. 4: Please provide the cost estimates and all related workpapers
(in electronic format with formulae intact) for both the undergrounding of the incremental
1.4 miles of transmission line to Owl Rock Road and for the 8 miles of distribution line
from the Wood River Substation to Owl Rock Road.
RESPONSE TO REQUEST NO. 4: Please see the attached Exce! files for the
requested information. As context, the attached segment estimates were used by the
Blaine County Planning & Zoning Commission to rank and prioritize segments for
potential undergrounding. These estimates were not used by ldaho Power to determine
the surcharge estimate, nor will they be used to determine the final surcharge amount.
As detailed in the Company's petition, the final surcharge amount for collection from
Blaine County wil! be the difference between the updated CPCN Route estimate and the
total cost of the constructed Owl Rock Road Route.
The attached files are as follows:
The response to this Request is sponsored by Eric Hackett, Projects and Design
Senior Manager, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 7
Attachment Description
1 Summary of Underground lncrementalCosts. This file accumulates the
information gathered from the remaining files and calculates the total
incremental costs to underground the 8 miles of distribution line (line
segments 2, 3 and 4) along Buttercup Road and East Fork Road and
the 1.4 miles of transmission from Elkhorn Road to Owl Rock Road..
2 Costs for Undersroundinq Distribution Seqment 2
3 Costs for Underqroundinq Distribution Seoment 3
4 Costs for Undergrounding Distribution Segment 4
5 Cost Reduction for Distribution Underbuild Costs
6 Cost Reduction for Steel Pole Costs
7 Cost Estimate - Underground Transmission - Ketchum Substation to
Owl Rock RoadICost Estimate - Underground Transmission - Ketchum Substation to
Elkhorn Road
REQUEST NO. 5: Please provide the "segment-by-segment' cost estimates
provided to the Blaine County Planning & Zoning ("P&Z') Commission as described in
Adelman's testimony.
RESPONSE TO REQUEST NO.5: Mr. Adelman's testimony states on Page 19,
Line 6:
At the request of the P&Z Commission, ldaho Power identified five
segments along the route of the Transmission Line and provided separate
incremental cost estimates for each segment for burying the Transmission
Line and also burying the existing distribution Iine in those segments where
the distribution line is present. The P&Z Commission requested these
"segment-by-segmenf' cost estimates to evaluate which segments might
be worth burying with County funding. The burial costs were estimated as
"incremental costs" over the cost of overhead construction for the
Transmission Line.
Mr. Adelman's testimony states on Page 10, Line 1
ldaho Poweralso provided a "placemat" drawing of the CPCN Route,
showing the estimated cost of burying the new Transmission Line and
existing distribution line in each of the five Transmission Line segments
reviewed by the P&Z Commission. The Transmission Line Route
"Placemat" from Blaine County Planning & Zoning Proceedings can be
found in Exhibit 1.
Accompanying this Response is another copy of the "Placemat" attached to Mr.
Adelman's testimony as Exhibit 1. The Placemat divides the Transmission Line into five
segments and shows (1) the incremental cost estimate for burying the Transmission Line
in each segment and (2) the incremental cost estimate for burying the existing distribution
line in Segments 24. Segment 5 includes three different options for burying the
Transmission Line, extending south from Elkhorn Road to (1) North Hospital Drive, (2)
South Hospital Drive, and (3) Owl Rock Road.
The response to this Request is sponsored by Ryan Adelman, Vice President of
Power Supply, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 8
REQUEST NO. 6; Please identiflt the cost estimate that will be used to determine
the cost of the origina! Certificate of Public Convenience and Necessity ('CPCN') route
used for determining the actual cost of additional Owl Rock Road Burials. Specifically,
wil! it use the updated version as described in Adelman's testimony ratherthan the original
CPCN estimates?
RESPONSE TO REQUEST NO. 6: ldaho Power proposes using a final CPCN
Route estimate (not yet developed) as the baseline to determine incremental cost of the
actual Owl Rock Road Route. The Company provided the two existing CPCN Route
estimates as important background with respect to route cost and siting.
Mr. Adelman's testimony states on Page 17, Line 4:
ldaho Power's cost estimate for the CPCN Route Transmission Line
was $30 million in the 2016-2017 Commission CPCN proceedings. The
Company prepared an updated $35 million cost estimate for the CPCN
Route in 2019, working with its engineering consultant, Power Engineers of
Hailey, one of the leading underground transmission engineering firms in
the United States. Exhibit 4 is the updated CPCN Route cost estimate from
2019.
The updated CPCN Route cost estimate includes a number of micro-
siting adjustments for Transmission Line pole locations (as requested by
the P&Z Commission) and several ldaho Power electricalsystem upgrades
that could be more efficiently and economically installed as part of the
overall Transmission Line project (such as installing a new ring bus at the
Wood River Substation to enhance localswitching capacity).
ldaho Power plans to prepare a final cost estimate of the CPCN
Route with Power Engineers when the Transmission Line construction is
ready to begin on the Ow! Rock Road Route. This timing will allow ldaho
Power to utilize the most current cost information available for both
overhead and underground transmission construction from the pre-
construction pricing for the Owl Rock Road Route.
As indicated in testimony, ldaho Power developed two prior cost estimates for the
CPCN Route: (1) the $30 million cost estimate from the 2016-2017 Commission CPCN
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 9
proceedings and (2) the updated $35 million cost estimate prepared for the CPCN Route
in 2019.
As indicated in the third testimony paragraph above, ldaho Powerwould use a final
updated CPCN Route cost estimate to calculate the incrementa! cost of the Owl Rock
Road Route. This finalcost estimate would be prepared with Power Engineers when the
Transmission Line construction is ready to begin on the Owl Rock Road Route. This
timing will allow ldaho Power to (1) review the most current cost information available for
both overhead and underground transmission construction from the pre-construction
pricing for the Owl Rock Road Route and (2) use this current information to provide the
final cost estimate of the CPCN Route.
The final cost estimate of the CPCN Route would then be subtracted from the
actual, post-construction cost of the Owl Rock Road Route to determine the incremental
cost of the Owl Rock Road Route to be reimbursed through the Surcharge.
The response to this Request is sponsored by Ryan Adelman, Vice President of
Power Supply, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 10
REQUEST NO. 7: Please provide detailed cost estimates and all related
workpapers (in electronic format with formulae intact) for the original CPCN route that
was used in Case No. IPC-E-16-28 and for the CPCN route that will be used to calculate
the actualcost of the additionalOw! Rock Road Route burials as described in Adelman's
testimony.
RESPONSE TO REQUEST NO.7: Please see the attached Exce!file forthe cost
estimate for the original CPCN route. As noted in Response to Staffs Request No. 6, the
cost estimate for the CPCN route that will be used to calculate the actual cost of the
additional Owl Rock Road Route burials will be prepared closer to the time of actual
construction of the Owl Rock Road Route.
The response to this Request is sponsored by Ryan Adelman, Vice President of
Power Supply, ldaho Power.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 11
REQUEST NO. 8: Please provide maps showing the layout and identiff the
location of the infrastructure contained in the cost estimates for the following:
a. The original CPCN route.
b. The origina! CPCN route updated to reflect the updated cost estimate discussed
in Adelman's testimony.
c. The segment-by-segment route alternatives provided to the Blaine County P&Z
Commission.
d. The final route agreed to by Blaine County that is included for recovery in this
Application.
RESPONSE TO REQUEST NO. 8:
a. The map of the original CPCN Route is provided in Aftachment 1 to this request.
The point labgled Transition Point 1 represents the approved CPCN configuration.
b. Mr. Adelman's testimony states on Page 17, Line 4:
A. ldaho Powe/s cost estimate for the CPCN Route Transmission Line was
$30 million in the 20'16-20'17 Commission CPCN proceedings. The
Company prepared an updated $35 million cost estimate for the CPCN
Route in2019, working with its engineering consultant, Power Engineers of
Hailey, one of the leading underground transmission engineering firms in
the United States. Exhibit 4 is the updated CPCN Route cost estimate from
2019.
The updated CPCN Route cost estimate includes a number of micro-siting
adjustments for Transmission Line pole locations (as requested by the P&Z
Commission) and several Idaho Power electrical system upgrades that
could be more efficiently and economically installed as part of the overall
Transmission Line project (such as installing a new ring bus at the Wood
River Substation to enhance local switching capacity).
The map of the 2019 updated CPCN Route is very similarto the map of the original
2016 CPCN Route provided in response to Request No.8(a) above. Most of the 2019
adjustments to the CPCN Route are not visible on the map because the changes are
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 12
geographically small or updates to electrical system equipment that would not show on
an overhead map - i.e., the "micro-siting adjustments for Transmission Line pole
locations" and "electricalsystem upgrades" referenced in Mr. Adelman's testimony above.
The 2019 updated CPCN Route is shown on the "Placemat" map aftached as Exhibit 1
to Mr. Adelman's testimony and as a response to DR No. 5.
ldaho Power has a detailed "plan and profile" engineering drawing of the 2019
updated CPCN Route, which shows each proposed pole location for the new transmission
line along the CPCN Route, including the "micro-siting' pole adjustments requested by
the Blaine County P&Z Commission. ldaho Power did not include this "plan and profile"
drawing, as it is a very large document, but can provide it at the request of the PUC Staff.
c. The "Placemat" map attached as Exhibit 1 to Mr. Adelman's testimony also shows
"The segment-by-segment route alternatives provided to the Blaine County P&Z
Commission', as requested in Request No. 8(c) above. The Placemat breaks the
overhead portion of the CPCN Route (from the Wood River Substation to Elkhorn Road)
into five segments, showing the estimated cost for undergrounding the new transmission
line and existing distribution line in each segment (the distribution Iine is only Iocated in
segments 2-4). These five segments do not change the location of the Transmission Line
- the only change is if the transmission line and/or distribution line is buried in that
segment.
d. The "final route agreed to by Blaine County that is included for recovery in this
Application" is the Owl Rock Road Route as described in the Application. The location of
the Owl Rock Road Route is shown on Exhibit 3 to the Adelman testimony. This is the
same location as the CPCN Route - the only change is the burial of the 1.4 miles of
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 13
transmission line and 8.0 miles of existing distribution line as shown on Exhibit 3. Another
copy of Exhibit 3 is attached to this Response to Request No. 8(b) for reference.
The response to ffris Request is sponsored by Ryan Adelman, Vie President of
Power Supply, ldaho Power.
IDAHO POWER COMPANYS RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 14
REQUEST NO. 9: Please provide a proposed timeline for construction of the
redundant line.
RESPONSE TO REQUEST NO. 9: After Commission project approval, ldaho
Power will start easement negotiations with landowners along the Owl Rock Road Route
to acquire necessary easements for the overhead transmission !ine, the underground
transmission line, and the underground distribution lines. Once the easements are
negotiated, and fina! locations are known, ldaho Power will perform detailed design
including surveying, geotechnical explorations, and geothermal analysis. Long{ead
materials will be quantified and bid out to suppliers, and then purchased. Easement and
detailed design task are expected to take approximately one year. Construction would
follow and is estimated to take two years. Please see the attached schedule for details.
The response to this Request is sponsored by Eric Hackett, Projects and Design
Senior Manager, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 15
REQUEST NO. 10: PIease provide the supporting documentation and calculations
for the net present value of the 2O-year surcharge referred to on page 15 of witness
Tatum's testimony.
RESPONSE TO REQUEST NO. 10: Please see the attached Excelspreadsheet
for the calculation of the net present value of the 2O-year surcharge.
The response to this Request is sponsored by Mark Annis, Regulatory Consultant,
ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 16
REQUEST NO. 11: Please describe and provide documentation on how the
allocation and collection of the surcharge would change if the Company included
Schedule 15 - Dusk to Dawn Lighting, Schedule 40 - Unmetered, and Schedules 41 and
42 -frafic Control customers.
RESPONSE TO REQUEST NO. 11: A 3 percent surcharge applied to Schedules
1 5, 40, 41 , and 42 would collect approximately $7,203 annually based on 2020 revenues.
Under the Company's cap-and-spread method, that $7,203 was spread to the two
broader categories of customers (ResidentiaUSmall General and Non-Residential). The
result of spreading this amount to the other categories was an increase of $0.02 per
month, from $3.40 to $3.42, to the Residential/Small Generalcategory surcharge and an
increase of $0.10 per month, from $14.26 to 14.36, to the Non-Residential category
surcharge. Given the complexity (i.e., application of the surcharge at the fixtureJevel)
and equity concerns (i.e., double application of surcharge) of applying the surcharge to
Schedules 15,40,41, and 42-and considering the minimal impact of "spreading'these
Schedules' revenues to the broader surcharge categories-ldaho Power determined that
removal of these Schedules from the surcharge application was the optimal approach.
Please see the attached Excel spreadsheet for the supporting calculations.
The response to this Request is sponsored by Mark Annis, Regulatory Consultant,
ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 17
REQUEST NO. 12: Please provide a copy of the Backup Power Report referred
to on page 7 of the Company's Petition. Please also include allassociated workpapers.
RESPONSE TO REQUEST NO. 12: Attached is a copy of the .Northern Wood
River Valley - Local Backup Electrical Supply Report" from October 2016.
The response to this Request is sponsored by Eric Hackett, Projects and Design
Senior Manager, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 18
REQUEST NO. 13: Please provide a copy of the Company's 2020 revaluation of
the Back Up Power report referred to on page 8 of the Company's position and include
all associated workpapers.
RESPONSE TO REQUEST NO. 13: During Idaho Powe/s discussion with the
Blaine County Commission in 2020, Blaine County Commissioner Dick Fosbury, as well
as other Blaine County stakeholders, asked the Company to revisit its prior evaluation of
alternative energy options in the Backup Power Report (included in response to Staff
Request No. 12).
Recognizing that altemative energy costs have fallen since the Backup Power
Report was developed in 2016, ldaho Power conducted a brief re-evaluation of project
costs using updated pricing from the same source as the origina! report (Lazard). On
October 7,2020,ldaho Power sent a letter to the Blaine County Commission, via Ronald
Williams, with the results of the analysis (included as an attachment to this response).
The letter states:
"The [Backup Power] Report analyzed diesel generation, natural gas
generation and solar generation as potentia! backup power sources, after
determining thatwind generation, geothermalgeneration and biomass generation
were not viable alternatives for the Wood River valley-which remains the case
today. The installation costs and the annual maintenance costs for the three
backup energy sources analyzed in the Report would be significantly higher than
the installation and maintenance costs for the flransmission Linel Project: Diese!
Engine ($57 million /$1 million), Gas Turbine ($1Ot million/$0.455 million) and PV
plus Battery Storage ($92+ million/$3.45 million). Diesel Engine and Gas Turbine
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 19
technologies have not changed significantly since 2016 and remain substantially
more expensive than the Transmission Line. Battery Storage technologies have
advanced since 2016, but still cannot cost-effectively meet the electrical demand
of the north valley. The Report analyzes a combined solar photovoltaic ("PV') and
battery energy storage system with 50 MW of battery generation added to the
Ketchum Substation and 15 MW added to the Elkhorn Substation, with the
batteries sized to meet energy needs of the north valley for only one-day outage.
The total installation cost of this system is estimated at $924 million in the Report,
plus ongoing O&M costs of $3,450,000 per year. Even if one assumes a battery
system alone (without solar PV generation) with a reduced capital cost of
$350/k!ryh2, the estimated total instatlation cost of the battery system would be
$429 million. The Transmission Line cost is far lower and would be able to meet
the north valley's total energy needs on a continuous basis, rather than for just one
day, and will allow ldaho Power to reconstruct the existing transmission line without
interruption to the north valley."
ln the Backup Power Report, ldaho Power used capital, operations, and
maintenance costs from Lazard's Levelized Cost of Energy Analysis-Version 9.0 from
201s.
!n its 2020 review of alternatives, ldaho Power focused on the cost of batteries, as
any renewable/clean alternative to the Transmission Line would require dispatchability.
The Company used updated costs from the same source (Lazard) in its Levelized Cost
of Storage Analysis-Version 5.0. To arrive at the new storage capital cost of $350/k\.,ryh,
ldaho Power identified a middle value in Lazard's range of baftery capital costs for
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 20
Transmission & Distribution ($ZZS - $469/k!ryh). Using the same battery size and
performance assumptions in the Backup Power Report (baftery output ol -'1,226 M\ /h),
ldaho Power assessed that the cost of a battery alternative to the Transmission Line
would be approximately $429 million ($350/k!ryh x 1,226,000 k\ Jh).
Given that the cost of the battery component alone would cost 12 times more than
the Transmission Line at the updated CPCN cost of $35 million, ldaho Power did not
consider it necessary to evaluate updated costs of solar. Any solar costs would be additive
to the storage component, as solar alone would not be a sufficient replacement to the
Transmission Line.
The response to this Request is sponsored by Eric Hackett, Projects and Design
Senior Manager, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 21
REQUEST NO. 14: Please provide a copy of the Blaine County's non-scientific
survey of its residents as mentioned on page 16 of the Gompany's Petition. Please
include the process forgathering the results, along with a copy of the survey and allother
workpapers associated with it.
RESPONSE TO REQUEST NO. 14: Please see the three attached documents
provided to ldaho Power by Blaine County in order to respond to this discovery request.
ldaho Power did not direct, nor have any involvement with, any aspect of this survey.
Questions regarding the survey should be directed to Blaine County.
The response to this Request is sponsored by Pat Hanington, Corporate
Secretary, ldaho Power.
Respectfully submitted this 21st day of October 2021.
Mzdat4-
DONOVAN E. WALKER
Attorney for ldaho Power Company
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF -22
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 21st day of October 2021,1 served a true and
correct copy of the within and foregoing IDAHO POWER COMPANY'S RESPONSE TO
THE FIRST PRODUCTION REQUEST OF THE COMMISSION STAFF upon the
following named parties by the method indicated below, and addressed to the following:
Blaine County Board of County
Commissioners
2016 1st Avenue South, Ste. 300
Hailey, lD 83333
Tim Graves, Chief Deputy BIaine
County Prosecuting Attorney's Office
2191st Avenue South, Suite 201
Hailey, lD 83333
Blaine County Land Use Department
c/o Tom Bergin
219 1st Avenue South, Suite 208
Hailey, lD 83333
Ronald Williams
HAWLEY TROXELL ENNIS & HAWLEY
877 West Main Street, Suite 1000
Boise, ldaho 83702
Kiki Leslie A. Tidwell
704 N. River St. #1
Hailey, lD 83333
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[e-mail]
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tq raves@co. blaine. id. us
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tberq [e-mail]. id. us
_Hand Delivered
_U.S. Mail
_Overnight Mail
_FAXX Email
rwill iams@ hawlevtroxel I. com
_Hand Delivered
_U.S. Mail
_Overnight Mail
FAX
X Emai!
[e-mail]
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 23
John R. Hammond, Jr.
Dayne Hardie
ldaho Public Utilities Commission
11331 W. Chinden Blvd.
Bldg.8, Ste.201-A
Boise, lD 83714
_Hand Delivered
_U.S. Mail
_Overnight Mail
_FAXX Email
[e-mail]
davn. hardie@puc. idaho.qov
Christy Davenport, Legal Assistant
IDAHO POWER COMPANY'S RESPONSE TO THE FIRST PRODUCTION
REQUEST OF THE COMMISSION STAFF - 24
BEFORE THE
IDAHO PUBLIC UTILITIES COMII,IISSION
CASE NO. IPC-E-21-25
IDAHO POWER GOMPANY
REQUEST NO,3
ATTACHMENT 1
SEE ATTACHED SPREADSHEET
BEFORE THE
IDAHO PUBLIC UTILITIES GOMMISSION
GASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO.4
ATTACHMENTS 1 .6
SEE ATTACHED SPREADSHEETS
BEFORE THE
IDAHO PUBLIG UTILITIES COMMISSION
CASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO.4
ATTACHMENT 7
6&3flBHFtr
Preliminary
ldaho Power
Hailey to Ketchum 138kV Underground Transmission Line
Near Owl Rock Road behind Trailer Park to Ketchum
Summary of Cost - Option 2
Notes:
Additional cable accessories consist of the following components:
Grounding system for vaults
Link boxes
Cable clamps
Continuity conductor
Jacket integrity test
Communication system consists of the following:
Terminal equipment and handholes
Fiber-optic cable, feet
2" conduit, feet
Assumed rock excavation for 30% of route
Assumed backfill comprised of 100% flowable fill
No dewatering for open trenching included, special installation methods include dewatering in cost
No real estate or permitting included
No temperature monitoring included
Engineering includes SWPPP costs
Big Wood River Bridge Crossing Project costs NOT included
Cost estimate does not include Cost Loading (ldaho Power Breakdown)
ldaho Power internal costs not included
20 ft wide of pavement repair assumed on highway, 5 ft in city streets
Due to the volatility of metal costs, the cable material prices could increase
1 spare reel (2500 ft), 1 spare termination, 1 spare anester, 2 spare splices included
1
2
3
4
5
6
7
8I
10
11
12
13
14
SUMMARY XLPE Cable S
Tota! Cost
Material
Costs Labor Gosts
Duct Bank $3.458.20s 580
Trenchless lnstallations $58,800 $il,100 $112,900
Soice Vaults $96.000 s280.000 $376.000
Cable $2,300,000 $825,000 $3,125,000
Solices $232.000 $216.000 $4/t8.000
Terminations $58.100 $48.000 $106.100
Anesters $17.500 $15.000 $32.500
Additional Cable Accessories $119.400 $140.600 $260.000
Communication Svstem $51.300 $70.100 $121.400
Termination Structures $170.000 s115.000 $285.000
Mob/Demob $o $280,000 $280,000
Enoineerino and Construction Manaoement $0 $625.000 $625.000
SUBTOTAL s5.658.475 s6.127.005 $11.785.'40
10% Continoencv $565,848 $612,701 $1,178,549
TOTAL $6.221.323 $6.739.706 $12.964.029
HLY 019-0982 (DES42) |PCO (10/15/18) JAJ 118644 REV. W
6&nre,HFI?
Preliminary
ldano Power
Hailey to Ketchum 138kv Underground Transmission Llne
Near Owl Rock Road bohind Trailer Park to Ketchum
750 kcmil Cu
3 Cables
628 Amps
'17963 fs6t 3.4 miles
OPTION 2
Prapared by: DM
Checked by: JAJI Numbor of Duct Banks
4 Numbor of Cable Ducts'l Number of Comm Ducts
Descriptlon Quantlty Mat rlal Prlce Lebor Prlca Total Prlco
a
no
a
HLY 019-0982 (DES-02) IPCO (t0i l5/18) DM l 18644 REV. W
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO.4
ATTACHMENT 8
6&3 POWER,
ENG'NEERS
Preliminary
ldaho Power
Hailey to Ketchum 138kV Underground Transmission Line
Wood River Substation to Ketchum Substation
Summary of Cost
Notes:
Additional cable accessories consist of the following components:
Grounding system for vaults
Link boxes
Cable clamps
Continuity conductor
Jacket integrity test
Communication system consists of the following:
Terminal equipment and handholes
Fiber-optic cable, feet
2" conduit, feet
Assumed rock excavation for 30% of route
Assumed backfill comprised of 100% flowable fill
No dewatering for open trenching included, special installation methods include dewatering in cost
No realestate or permitting included
No temperature monitoring included
Engineering includes S\A/FPP costs
Cost estimate does not include Cost Loading (ldaho Power Breakdown)
ldaho Power internal costs not included
20 ft wide of pavement repair assumed on highway, 5 ft in city streets
Due to the volatility of metal costs, the cable material prices could increase
1 spare reel (2500 ft), 1 spare termination, 1 spare anester, 2 spare splices included
Access road construction for splice vault maintenance not included
1
2
3
4
5
6
7I
o
10
11
12
13
14
SUiIMARY XLPE Gable S 'stem Costs
Total Cost
Material
Gosts Labor Gosts
Duct Bank $2,755.E08 84.697.075
Trenchless lnstallations s95.350 $195.400
Spice Vaults $135,000 $1s0,00($285,000
Cable $505.500 $1.953.500
Splices $225,000 $310,000
Terminations $150.000 $208.100
Anesters 7 $15.000 $32.500
Additional Cable Accessories $87,700 $167,800
Communication System $50.700 $89.800
Termination Structures 1 $117.000 $292.000
Mob/Demob i0 $300.000 $300.000
Enqineerinq and Construction Manaoement $625.000 $625.000
SUBTOTAL $5.077.058 $9.156,{75
30% Gontinoencv $1.523.118 $2,746,854
TOTAL 55.500.176 sl1.903.029
HLY 019-0982 (DES42) rpCO (08/15/19) LB 1186//l REV. AA
6E1T^PHFIT
Preliminary
tolno Fower
H.llcy to K.tchum 13!w Undcrground Ttrnsmbilon Llne
All Underground
760 kcmll Cu
3 C.bl.!
02E Amp3
10997 t .t 2.1 mll.3
UI D'ZUI !
P?opusd by: LB
Chocl.d by: DllI l{umber o, Duct B.nksI Number o, Crble Ducts
2 ilumb.r ot Comm Ducti
O.lcrlptloo Quenuty L!.rLl P.lc.Lrbor Prlc.Tohl Pdc.
on
a
no
a
a
HLY 0re4e82 (DES{2) IPCO (08/r 5/ r e) LB I l86l{REV M
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO.5
ATTACHMENT 1
North Valley Redundant Line Project
Location: North Hospital Drive
to Elkhorn Road
Distan(e: 0.7 Miles
Transmission uG cod: 11,800,000
tcgrncnt 5 Lo(ation: South Hospital Drive
to Elkhorn Road
Distance: 1.1 Miles
Transmission UG cost: 12,700,000
Location: or,vl Rock to Elkhorn Rd
oistance: 1.4 Miles
Trensmirsion UG Cost 14,100,000
tegmant a Lo(ation: East Fork Road to Hospital
Dirtance: 3.2 Miles
Distribution UG Cort: 12,000,000
Tranrmission UG Cost: 18,30O,0m
Location: Highway Croseing
Transmirsion UG Cost: tl,500,m0
Segmcnt I Location: Wood River Substation
to Buttercup Road
Distance: 0.5 Miles
Transmisslon UG cost: 15,000,000
S€gment 3 Lo€ation: Buttercup Road/Hury 75 lnterrection
to Eart Fork Road
Distance: 2.9 Miles
Distribution UG Cost: 12,700,000
Transmission UG Cost: t9,000,000
Segment 2 Location: Buttercup Road /W. Meadow Drive
to Euttercup Road/Hwy 75 lnteBectlon
Distance: 1.6 Miles
Distribution u6 cost: tl,000,u)0
Transmi3iion UG Cost: 15,900,000
*
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPG-E-21-25
IDAHO POWER COMPANY
REQUEST NO.7
ATTACHMENT 1
SEE ATTACH ED SPREADSHEET
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO.8A
ATTACHMENT 1
H.ll.y to Kctchum
Undarlround Tranamladon Llna Opllon
TEEthn Polilt
r - PDpolad Ovcfiod TEnmitdon Lha
. . , Popoaad t nddetund Tndfifih Lha
{- subrbton.
x
A0orE1u
-
Csse No. IPCE-1&28
D. Angell, IPC
Pege I of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E.21-25
IDAHO POWER COMPANY
REQUEST NO.8B
ATTACHMENT 1
Owl Rock Road Route
North Valley Redundant Line Project
Locatloo: Owl Rock Road to
Elkhom Road
Dlrt ncc: 1.tl Miles
Tr.nsml$lon uG Cost: 54,100.000
Locatlon: South Hospital Drive
to Buttercup Rd,/
w. Meadow Drive
Dlrt'ncc:8.0 Mlles
DHdhdoo UG Cost: 55,700,000
Oflta.d Tr6irri(e UDd.tdrd Dartlbltbn SGtbn
(hrh.d lrrsl$br tlo Dktlbulbn Sqtbo
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPG.E.21.25
IDAHO POWER COMPANY
REQUEST NO.9
ATTACHMENT 1
Ubod BrilVrl., Oor$u.lon Tlm..In.
^ l*llr..,. r r., . l*itr., ^Y!,:f.., .,.., . lYtfi -, - r -, ^Yt??-, ^ ,-, .HlUrlrlrlalrln
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO. 10
ATTACHMENT 1
SEE ATTACHED SPREADSHEET
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWERCOMPANY
REQUEST NO. 11
ATTACHMENT 1
SEE ATTACH ED SPREADSH EET
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-21-25
IDAHO POWERCOMPANY
REQUEST NO. 12
ATTACHMENT 1
3Em.
An lD @RPcotnparv
Northern Wood River
Valley-Local Backup
Electrical Supply Report
Customer Operations
Planning
October 2016
@ 2016 Idaho Power
Idaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Teeue oF CoNTENTS
Table of Contents
List of Tables
i
i
ll
ll
List of Figures.............
List of Appendices
List of Acronlms ll
.l
.3
,3
,4
,4
.4
.5
.5
.5
.5
.5
Executive Summary..
Land and Interconnection Requirements .................
Resources Considered
Diesel Reciprocating Generators
Natural Gas Combustion Turbines.................
Battery Energy Storage System
Solar Photovoltaic.........
Biomass....
Results......
Total Installed Costs
o&M (rncf
Conclusions
References
Table 1.
Table 2.
Table 3.
LST OF TABLES
.....6
,....6
.....6
.....7
.....7
..... IResource cost summary
Land and interconnection costs
Capital costs..........
,,4
....6
Page i
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Table 4.
Table 5.
O&M costs
Fuel costs for a l-day transmission outage
Lsr oF FIGURES
Figure l. December 3l,20l5,load profile......
LIsr oF APPENDIcES
Appendix A
Property Protection Analysis Report
Appendix B
Power Usage Distribution
Appendix C
City of Ketchum Solar Generation Assessment
Appendix D
Microgrid Study Results
LIsr oF AcRoNYMS
BESS-Battery Energy Storage System
CT-Natural Gas Combustion Turbine Generation
DRE-Diesel Reciprocating Engine Generation
F-Fahrenheit
HOMER-Hybrid Optimization of Multiple Energy Resources
INL-Idaho National Laboratory
kV-Kilovolt
kW-Kilowatt
m2-square Meter
MW-Megawatt
MWh-Megawatt-Hour
NREL-National Renewable Energy Laboratory
6
7
Page ii
ldaho Pourcr Company Northem Wood River Valley Local Backup Electical Supply Report
O&M{peration and Maintenance
PV-Photovoltaic
Page iii
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
ExecuruE SUMMARY
This document presents the results of a preliminary study to provide the northem Wood River
Valley customers served by the Ketchum and Elkhorn substations with backup electrical
supply from locally sited generation. The resources considered in the study are diesel
reciprocating engine (DRE), natural gas combustion turbines (CT), photovoltaic (PV) plus
battery energy storage system (BESS), geothermal generation, and biomass generation.
The analysis was performed using industry-standard energy resource simulation software,
HOMERo, which was developed by the National Renewable Energy Laboratory NREL).
The capital, operations and maintenance (O&M), and fuel cost estimates for the resources
identified above were obtained from Lazard's Levelized Cost of Energt Analysis-Version 9.0
(Lazud 2015a). Idaho Power also compared the Lazard estimated with pre-engineering
budgetary quotes from several vendors. Additionally, the Idaho National Laboratory (INL), with
more than 1,000 megawatts (MW) of hybrid power, solar, and wind energy systems deployed at
Department of Defense and industry/utility sites around the world, provided independent
technical review and feedback on the analysis and report.
Table I summarizes the estimated equipment, installation, O&M, and fuel cost of each resource.
The following assumptions were made: l) the area served requires 60 MW of peak power based
on an Idaho Power study of the requirements to maintain residential and commercial building at
55 degrees Fahrenheit (F) (see Appendices A and B); 2) the total energy consumed during the
24-hour period would be 1,150 megawatt-hours (MWh); and 3) the PV peak output of the area
would be 21 MW based on Idaho Power's Solar Availability in Ketchum study (see Appendix C).
The diesel generator and battery equipment costs were compared against budgetary quotes
received during the last year. This study and the estimates provided are preliminary and
concepfual in nature. Therefore, Idaho Power cannot guarantee any cost estimates based on
this preliminary analysis.
Table 1. Resource cost summary
Resource
Manufacturer
Equipment Gost
Total lnstallation
Cost
O&M Annual
Gost
24-Hour
Fuel Gost
Diesel Engine
Gas Turbine
PV plus Battery Storage
$800/kw
$1500/kw
$800/kwh
$57,000,000
$101,000,000
$924,000,000
$1,000,000
$455,000
$3,450,000
$197,000
$41,000
$46,000
The analysis demonstrates that the most economical way to provide backup electrical supply
from local generation (i.e., a microgrid) is by either diesel engines or gas turbines. With respect
to the other resources considered, the study area does not have a geothermal resource suitable for
electrical generation, and biomass generation costs are significantly higher and the startup time
would be substantially longer than for diesel engines or gas turbines. Additionally, the biomass
generation would require more investigation into the availability of and cost to extract the local
Page 1
Norhem Wood RiverValley Local Backup Electical Supply Report ldaho Power Company
biomass material. Finally, the large winter €nergy requiremeirt results in a cost-prohibitive
battery systern 61this time.
The study does not address, among otherthings, the abilityto site, permit, ordetermine the
operational limitations that might be imposed on the electrical gsneration resources. Idaho Power
contacted Intermountain Gas to veriry the abilityto supply natural gas to fuel the generators.
However, a resporule was not provided by the time ofreport distibution.
Page2
ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
Scope
The intent of this study is to provide a preliminary examination of the resource capital (including
equipment procurement, installation, land, and gdd integration costs); operation and maintenance
(O&M); and fuel costs of local generation resources that may be used to supply backup electrical
energy for the customers served by the Ketchum and Elkhorn substations. The assessment of the
capital and O&M costs are based on the pre-engineering estimates of the performance and cost
of commercial or near-commercial technology available at the time of this study.
Local permitting requirements, environmental mitigation, and noise levels for diesel and gas
turbine plants were not considered in this study.
SruoY
This study considered a scenario in which the 138-kilovolt (kV) Hailey to Ketchum ffansmission
line is out of service for a 24-hour period during the winter. The present winter peak load in the
area is 60 megawatts (M!V) and is projected to reach 65 MW by 2025. The model simulated a
single year in l-hour intervals using each resource and a combination of them. A previous study
shows that winter load cannot be substantially reduced by rotating outages but could be reduced
by l0 percent if thermostats could be automatically set to 55 degtees during an outage, resulting
in a reduction of the forecasted 2025 recentpeak loads (see Appendices A and B). A load profile,
shown in Figure l, modified to reflect reduced Bald and Dollar Mountain operations for
December 31,2015, is used to simulate the total energy consumed during the 24-hour period of
1,150 megawatt-hours (MWh). Idaho Power recognizes that a transmission sffucture failure
during the winter may require several days to repair. The 24-hour period is used merely to
determine a base cost. This cost could be multiplied by the desired days of backup service to
establish the total cost ofa local backup resource option.
Loadshape
62
60
58
56
==s4Eu,oJ
50
48
46
44051015
T'ime (hr)
Figure 1. December 31,2015, load profile
20 25
Page 3
Northern Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
With the transmission line out of service, the customers served by both Ketchum and Elkhorn
substations need to be served by the evaluated altemative resource. The study assumes Ketchum
and Elkhorn substations respectively supply 46 and 14 MW of the 60 MW peak load.
The generator sizes have been selected based on cornmercially available units that can manage
load restoration and provide reactive power requirernents of the loads. These selections result in
a total generation capacity of about 110% of the peak load.
Leruo AND lnrencoNNEcrpN REQUTREMENTS
Over one acre of land would be required for the diesel reciprocating or combustion turtine
generators. It is likely that additional land would be required to site the battery system.
The interconnection cost estimates include the transformer, protection, and control systems to
interface with the existing substations. The estimated land and interconnection costs are shown in
Table2.
Table 2. Land and interconnection costs
Substation Site Land Cost lnterconnection Cost Total
Ketchum
Elkhom
$1,306,800
$871,200
$862,000
$558,000
$2,168,800
$1,429,200
Total $2,178,000 $1,420,000 $3,598,000
ResouncEs CottstoERED
The resources analyzed in the study are diesel reciprocating engrne generation (DRE), natural
gas combustion turbines (CT), photovoltaic (PV) plus battery energy storage system (BESS),
geothermal generation, and biomass. The costs for each resource were obtained from Lazard's
Levelized Cost of Energt Analysis-Version 9.0 (Lazard2015a). The diesel engine and battery
storage costs were compared against budgetary quotes received during the last year. The Idaho
National Laboratory GI.[L) provided feedback on their experience with the cost of the resources.
Diesel Reciprocating Generators
DRE remains the most corlmon choice for emergency power systems worldwide. It is a mature
resource that has provided backup power for decades. According to the Lazard, (2015a) report,
the capital cost for installing DRE can range from $500 per kilowatt (kW) to $1,000 per kW.
This price does not include the cost of land or the cost to interconnect to the system. The price of
diesel fuel is assumed to be $2.50 per gallon, and the O&M costs for a diesel generator are $15
per kW per year and $15 per MWh (Lazard20l5a). These reciprocating generators could be
fueled by natural gas with the fuel pricing shown in the following Natural Gas Combustion
Turbine section.
A quote from a vendor during the third quarter of 2016 shows the price of diesel generators is
close to the upper end of the range discussed in theLazardreport.
Page4
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Natural Gas Combustion Turbines
The use of gas turbine technology, while not as coilrmon as diesel generation, has increased in
recent years as an altemative to providing backup power. According to the Lazard (2015a)
report, ttre capital cost for installing CT can range from $2,500 per kW to $2,700 per kW.
However, the INL provided information that shows the cost of CT as being as low as $1,500 per
kW. The price does not include the cost of land or the cost to interconnect to the system. The fuel
price for natural gas is $0.124 per cubic meter (m3) and the O&M costs associated with CT are
$6.85 to $9.12 perkW per year and $7.0 to $10.9 per MWh.
Battery Energy Storage System
One of the emerging technologies used forproviding backup power is the BESS. Even though
batteries do not generate electricity, they can be charged from the grid and can provide backup
power when the grid is off-line. Because of the size and application of the proJect, a flow battery
was chosen for the study with a price of $800 per kWh (Lazard 2015b).
Solar Photovoltaic
The solar capability of the Ketchum area was determined by approximating the amount of
residential and commercial roof area suitable for PV installation and following National
Renewable Energy Laboratory NREL) guidelines. The results show that an estimated roof area
of 112,578 square meters (m2) is suitable for roof-mounted PV installation. See Appendix C for
the complete study.
Based on the calculated roof area available to install solar PV, the total amount of PV that could
be installed in the Ketchum area is 21.4 MWa". The solar irradiance was obtained for the
Ketchum area using NREL's PVWatts calculator. This level of PV penetration may take many
years to achieve but is included in the study to represent a potentially reduced level ofenergy
storage requirements in the future.
Geothermal
The geothermal resource was reviewed through the NREL Geothermal Prospector tool
(NREL 2016) and is supported by an tdaho Deparhnent of Water Resources 1990 report (ID
DWR) reference by INL during a Wood River Renewable Working Group presentation on
geothermal. The NREL tool indicates the Ketchum area has class 2 and class 3 geotherrnal
resources. Both geothermal classes could support residential or cofirmercial heating but would be
inadequate for power generation. The INL researcher, during his presentation, identified only the
Magic Hot Springs thermal resource as suitable for electrical generation.
Biomass
According to the Lazard (2015a) report, the capital cost of installing biomass ranges from $3,000
per kW to $4,000 per kW. The installation cost for 60 MW of biomass generation would likely
exceed $200,000,000. The biomass option has not been fully evaluated based on the comparably
higher capital cost; large land requirements; and uncertainty of fuel capacity, expense and
emission requirements.
Page 5
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Resurrs
The analysis evaluated each resource total cost (capital, O&M) and the HOMER
simulation results. Additional simulation results are provided in Appendix D.
Total Installed Costs
The locations of the proposed diesel generators, gas turbines, and battery systems were split onto
the 2 main sites-50 MW of generation were added to the Ketchum Substation and l5 MW at
the Elkhom Substation. The capital costs for each resource are shown in Table 3. The resources
for the capital costs are based on the following: 1) the diesel generation price is based on the
Lazard (2015a) report and verified with a Wartsila Company budgetary level quote, 2) the gas
combustion turbine price is based on $1,500 per kW which is situated between the microturbine
price and the gas peaker plant in the Lazard (2015a) report, and 3) the battery price is based on
$800 per kWh for the battery system and assumes 2l MW of local PV installed by others. The
size of the battery was calculated based on the energy needs for a one-day outage. The capital
cost of the battery will increase if the backup power is needed for more than a single day.
Table 3. Capitalcosts
Resource Capitalcost
Diesel Generation
Gas Turbine
PV plus Battery System
$57,000,000
$101,000,000
$924,000,000
O&M Cost
There are two components to the O&M cost. The first is a fixed annual cost based on the size of
the generator and the routine start-up and operation of the generator, typically 4 hours per month.
The second component is directly proportional to the operation time of the generators during an
outage of the existing transmission line. Table 4 shows the fixed annual cost for fuel and O&M.
Table 4. O&M costs
Resource Fixed O&M (per year)
Diesel Generation
Gas Turbine
PV plus Battery System
$1,000,000
$4s5,000
$3,450,000
The study assumed the existing Hailey to Ketchum 138-kV ffansmission line was out of service
for I day. Table 5 shows the fuel cost when operating the diesel generators and gas turbines,
and the electricity cost (energy delivered to the battery with associated transmission and
substation costs) for charging the battery.
Page 6
ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
Table 5. Fuel costs for a l-day transmission outage
Resource Variable Fuel
Diesel Generation
Gas Turbine
PV plus Baftery System
$197,000
$41,000
$46,000
CottclusroNS
A study to provide backup power to the Ketchum and Elkhorn area using local generation
was performed. The study demonstrates that the use of DRE is the more cost-effective of the
local resources considered. A local geothermal generation resource is not available.
Biomass generation will require a significantly higher capital cost and require much more
resource investigation. Finally, a battery system is cost-prohibitive at this time.
RereneNcEs
Lazard. 20 I 5 a. Lazar d' s level ized cost of energy analysi s-Version 9. 0.
https : //www. lazard.com/perspecti ve/levelized-cost-of-enersv-anal vsi s-90/
Lazard.20l5b. Lazard's levelized cost of storage analysis-Version 1.0.
https://www.lazard.com/media/2391llazards-levelized-cost-of-storaee-analysis- l0.pdf.
INREL] National Renewable Energy Laboratory.2016. Geothermal prospector mapping tool.
https://maps.nrel.eov/eeothermal-prospector/. Golden, CO: NREL.
[ID DWR] Idatro Department of Water Resources. 1990. Geothermal Resource Analysis in the
Big Wood River Valley. https://www.idwr.idaho.eov/files/publications/wib30pl7-
geothermal-bi e-wood-river-valley.odf
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Northem Wood RiverValley Local Backup Elocfft-cat Supply Report ldaho PorcrCornpany
This page leftblank intentionally.
Page8
Appendix A
Property Protection Analysis Report
ntmlos!Poi,ER.
An nAiCOPPCoTEnY
Property Protection
Analysis Report
Ketchum Energy
Resilience Team
October 2016
O 2016 Idaho Power
Rev. 2
Teeu or CoTTENTS
Table of Contents.,
L'st of Appendices I
Background..
Methodology
I
I
Minimum Indoor Temperature I
Heat Loss Rate...........I
Heating Systemr Duty Cycle
Cold toad Pick Up Effect........
Other Considerations
Conclusion
References
LIsT oF APPENDIcES
Appendix A.A
Heat Loss Rate
Appendix A.B
Heating Capacrty and Duty Cyc1e......... .............8
Appendix A.C
Cold Inad PickUp.....
.2
.2
.3
.3
.3
..........9
.................... I
Page Ai
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
BnCxoRoUND
A multi-stakeholder team, including the City of Ketchum, Sun Valley Company, Idaho Power,
andNRG, attended the Rocky Mountain lnstitutes Electicity Innovation Lab (e-Lab) during
March of 2015. The team decided that four levels of electrical demand would be evaluated
relative to the local renewable resource capability: critical life safety, property protection,
summer peak load and winter peak load. This report addresses the property protection demand
required to maintain building heat at a level to avoid freezing water pipes during sub-zero
temperature conditions.
The report was updated October 2016 to improve readability.
MerxoDoLocY
The minimum amount of heat generation necessary to keep water pipes from freezing in homes
and businesses with a rotating outage is calculated based on the following elements:
Minimum indoor temperaturea
o
o
a
Heat loss rate
Heating capacity
Heating system duty cycle
A formal study can be conducted to determine the heat loss rate for homes in the Ketchum Area
and the minimum indoor temperature required to keep the pipes from freezing. If a formal study
is desired, it should be conducted during an extreme winter peak.
Minimum lndoor Temperature
The minimum requirement to protect property is based on maintaining a minimum temperature
inside homes and businesses. [t does not guarantee that pipes will not freeze, as all buildings are
not constructed in the same manner. Water pipe placement within exterior walls and along attics
will impact the likelihood that property damage occurs. The American Red Cross, Consumer
Reports, and State Farm all recommend maintaining an indoor temperature of 55oF to keep pipes
from freezing. The report will use 65oF because the buildings will need to be heated above the
point at which pipes would freeze, and then be allowed to cool over time in a rotating outage.
Heat Loss Rate
Heat loss determines how quickly indoor temperatures drop and how long the power must be on
to prevent damage.
Heat is lost in a variety of ways:
a Walls
Page Al
ldaho Power Company Northern Wood River Valley Local Backup Electrical Suppty Report
a
a
o
Windows
Ceiling
Floor
o Ventilation
a Infilnation
Heat loss for each of these ways can be estimated based upon a set of assumptions and equations.
This is done in Appendix A.
Heating Capacity
The heating capacity of a home or business is based on its heat strip size. The recommended heat
strip size can be determined based upon the size of the building and the region. An example
calculation for the Ketchum area can be found in Appendix B.
Heating System Duty Gycle
The duty cycle of the heating systern determines the amount of time that the systern can be off
compared to how long it must remain on to maintain a set temperature. The equation is located in
Appendix B. The calculation results in the heating system must remain on77o/o of the time in
order to keep the indoor temperature at or above 55oF and avoid frozen water pipes.
Cold Load Pick Up Effect
Under normal conditions in cold weather, the hundreds to thousands of homes and businesses
served by an area's substation do not have all of their heating systems, lights, and appliances
using power at the same time. The heating and refrigeration loads cycle on and offbased on
temperature. Due to the temperature cycling effect, a portion of the home and business heating
and refrigeration load will be offat a given time. This is known as load diversity.
When a transmission line is out of service, all buildings served from the substation lose power at
the same time. When service is restored after some period of time, more heating and refrigeration
equipment will be in an on-state at the same time. For greater outage periods prior to restoration,
the homes and businesses will require more time to bring the temperature up to thermostat
settings. This requires the substation to serve a greater amount of electrical load at the sarne time.
The condition where a substation restores electrical load following an outage is called cold load
pick up.
The distribution circuits out of the substation that serve customers in the Ketchum Area have a
12.5MVA loading design limit. Idaho Power does not normally the circuits beyond l0MVA. The
additional 20o/o reserve capacity is used to during situations such as cold load pick up. However,
the load on the circuits must be restored in sections resulting in less than I2.5MVA ofpower.
This requires carefully adding the circuit sections over time to allow load diversity to occur
within each section. If sections are added prior to the load diversity occurring, an overload will
Page A2
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
occur, the circuit will be taken out of service, and the restoration process will have to begin
again. The customers located in the most remote section will be restored last and are often out of
service two to four times as long as the customers located near the substation. A rotating outage
backup system would need to protect all of the customers from property damage. More details
regarding cold load pick up can be found in Appendix C.
Other Gonsiderations
The time for different houses to drop temperature varies widely based on their thermal mass,
square footage, tightness of construction, solar orientation, building use, wind speed and
direction, and other factors. Heat loss studies are inherently risky since incorporating all factors
is unfeasible and the consequences of a ruptured pipe can be substantial.
Gottcr-usroN
This study demonstrates that the heating system must remain on77%o of the time to protect the
property. Assuming rotating outages on the distribution circuits, the remote sections will
experience a restoration delay exceeding one hour due to cold load pick up effects. Therefore,
rotating outages to reduce load during transmission outages cannot prevent property damage for
all homes and businesses.
RereneNcEs
Preventing and Thawing Frozen Pipes [Web log post]. Retrieved June 2, 2015, from
http://www.redcross.org/prepare/disaster/winter-storm/preventine-thawing-frozen-pipes.
How to prevent your pipes from freezing and bursting [Web log post]. Retrieved June 2,2015,
from http://www.consumerreports.orgy'cro/news/2014/0 I /how-to-prevent-your-pipes-from-
freezinslindex.htm.
Preventing Frozen Pipes [Web log post]. Retrieved June 2, 2015, from
http://leamingcenter.statefarm.con/residence/maintenance/preventine-frozen-pipes/
Overall heat transfer loss from buildings - transmission, ventilation and infiltration [Web log
post]. Retrieved June 2,2015, from http://www.eneineerinetoolbox.corn/heat-loss-buildines-
d I l3.html.
Equipment Sizing Guide [Web log post]. Retrieved June 2,2015,from
http://www.homedepot.com/cataloe/pdflmaees/03/03682bd8-8921-4e23-beed-
884R25e0a57.pdf.
Calculating Home Heating Energy [Web log post]. Retrieved June 2, 2015, from
http ://hvperphysics.phy-astr. esu. edu/hbase/thermo/heatloss.html.
How Much Insulation Should Be lnstalled [Web log post]. Retrieved June 2,20L5, from
http://www.naima.org/insuLatiorr-kn-olvledge-base/residential-home-insulation/how-much-
insulation-should-be-installed. html.
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ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
Energy Ratings [Web log post]. Retrieved June 2,2015,fuom
httlr : //www. nfrc. ore/w indowratines/Enerev-ratines. html.
Comparison of Heat Loss by Sample Building Component [Web log post]. Rehieved June 2,
2015, from
http://www.qoosle.con/url?sa:t&rct:j&q:&esrc:s&frm:l&source:web&cd:7&ved:0cEYo
FjAG&url:http%3A%2F%2Fwww.waptac.org%2Fdata%2Ffiles%2Fwebsite docs%2Ftrainine
o/o2Fstandardized_curriculao/o2Fcurricula_resources0/o2Fheat-loss-calculation-
worksheet.doc&ei:XEwlVcCdOsTPsAX4ooBI&use:AFOiCNGUf03RAvwXJDeOgAFPDsC
WGs5nUA&siq2:XoT8uO_MXl4pea0XJsZrTA&bvm:bv. 9023 7346.d.b2w.
How Do the 2006 Residential and International Energy Codes Stack Up? [Web log post].
Retrieved June 2,2015, from http://www.neo.ne.eov/neq online/sept2006/sept2006.08.htm.
Residential Buildings Energy Code Summary 2009 [Web log post]. Retrieved June 2,2015,fuom
http://www.eooele.corn/url?sa:t&rct:j&q:&esrc:s&frm:l &source:web&cd:5&sqi:2&ved:0
CD eO Fi AE&url:http%3 A%2F%2 Fdeq.mt. eov%2FEnergf/o2 Fconservation%2 Fhomes%2 FN e
wHomes%2FpdfD/o2FEnerqyNotes RESID 09 Jan%252009.pdf&ei:XlOlVZT0HIeAysTqloH
wAe&usg:AFOiCNGRvOeAruOS5Lh03Nurqvw3uvOmhe&sie2:tnRpiCKOeljD99ZDxIDMIw
&bvm:bv. 9023 7346.d.b2w.
BTU Calculator [Web log post]. Retrieved June 2,2015, from http://www.calculator.net/btu-
calculator.html.
Chris Pollow, Idaho Power, Senior Engineer (personal communication, May 6,2015).
Todd Greenwell, Idaho Power, Program Specialist II (personal communication, May 6,2015).
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ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
Appendix A.A
Heat Loss Rate
For the following calculations, these assumptions were made:
o The building size is 2000 sq ft.
o The building is one level with 8 foot ceilings.
o An outside temperature of -2loF was assumed for the extreme peak.
Walls
The average heat loss through a wall can be determined by the following equation:
Heat loss rate (walls; = 9 =
Area.(, -*#rff ) - (Tinsiae -To,t,ia")
Thermal reststance of wall
Where:
Area = Heightyyoll' Lengthlryrs' (Nwnber of Walls)
Additional assumptions are n@essary to use the equation:
. The building length is approximately equal to the width.
. The window to wall ratio is 30%.
. The R-Value of the wall is 19.
Heat loss rate (walls) =(e.'(/Zpoo-, .4 ft ).(1 - 0.7).(6s - (-21))
,to ft2 'oF-' BTU /hr
BTUHeat loss rate (walls) = 4,5357;
Windows
Heat loss is greater through windows than through walls. A window-to-wall ratio can be
assumed for buildings to help with this calculation. Energy code guidelines tlpically state a
window to wall ratio of 12to l8o/o, but the actual ratio can be higher than 30%. 30% was
assumed for the calculations. If the window-to-wall ratio is higher than assumed, heat loss will
occur more rapidly.
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ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
The efficiency of windows is tlpically measured by a U-factor, which is the reciprocal of an R-
value. Most windows have a U-factor value between 0.15 and 1.20. Through a window
replacement program, a reasonable assumption for the U-factor is 0.35.
Heat loss rate (windows)
Area
T hermal r esistance o f wall
Heat loss rate (wtndows) =
('tr0'00. .3 . 8 . 4 ft'). (6s - (-21))
L ftz.oFSW
Heat loss rate (windows) = L2,923 BfU lhr
Ceiling
Attic insulation typically has an R-value of 49-60. Assuming R49
Heat loss rate (cetltng) =
2,O0Of*. (6s - (-21))
Window'-wilr'(Trn ia" - Tortrra")
4sm
Heat loss rate (ceiling) = 3,510 BTU /hr
Floor
Heat loss through the floor can be a complicated calculation, but it typically amounts to20-30o/o
of the total energy loss in a home. 25%will be used in the total heat loss calculation.
Ventilation and lnfi ltration
Ventilation is heat loss that occurs due to the venting of air from the heating system.
Infiltation heat loss occurs due to leakages in building construction and the opening and closing
of windows and doors.
Together they account for approximately 43o/o of the total heat loss.
Total Heat Loss Rate
The percentage of heat loss through the floor, ventilation, and infiltration total 68% of the total
heat loss. The remaining heat loss, 32o/o, is lost through the walls, windows, and ceiling. The
total heat loss can be obtained through the following calculation:
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ldaho PouorCompany Northem Wood River Valloy Local Baekup Electical Supply Report
Heat Loss Rate (walls) * Heat Loss Rate(wtndows) + Heat Loss Rate(cetling)
= 3ZVo'Total Heat Loss
Total Heat Loss _ 4,5358TU lhr * t2,9238-^T_u /tv * 3,5L0BTU /lv
0.32
Total Heat Loss = 65,5258fU /hr
PagaAT
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Appendix A.B
Heating Capacity and Duty Cycle
The heating capacity of the assumed building size can be found based on the region and heat
strip recommendations :
The Ketchum Area lies in Region 1 and a 2000 sq ft building would require a 25kW
heat stip.
o I kWh of energy is equivalent to 3,412 BTU.
The heating capacrty of the building is:
a
Heating Capacity = 85,300 BTU /hr
The duty cycle can the,n be determined using previous calculations:
Heattng Capactty = Heat strip size '!kwh
Heating Capactty -- 25kW '''u1-,1!r;u
Duty cycre Heatins system = m
Duty cycleseatins system= ffi
Duty Cycleseatins system = 0.77 (77o/o)
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ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Appendix A.G
Cold Load Pick Up
Through many years of operational experience, Idaho Power has determined that load increases
as indicated in Table 1 where:
Outage Duration is given in the format Hours:Minutes.
Percent Normal refers to the percentage of load that can be expected when power is
restored compared to the normal load before the outage occurred. As an exarnple, if there
is twice as much load when power is restored as there was before the outage occurred,
Percent Normal is 200o/o.
Table I
Cold load effect on load duration chart
Outage Duration Percent Normal
a
a
0:00
0:32
1:04
1:37
2:09
2:41
3:14
3:46
4:18
4:51
5:23
5:55
6:27
100.0%
162.0o/o
200.0Yo
234.0o/o
260.Oo/o
270.OYo
276.00/o
280.0o/o
283.0o/o
285.0o/o
287.0o/o
288.0%
289.00/o
Example: If a circuit is loaded to I0MVA normally and a power outage lasts 7 hours
(the coincidence factor has saturated), the load will be 28.9MVA when power is restored,
exceeding the \2.5MVA circuit rating. In this example, the load must be restored in at least
4 tiers. After each tier is restored, a period of time, tlpically around 20 minutes, must pass while
the coincidence factor decreases and the load diversity normalizes.
Table 2
Load tiers associated with cold load pick up
NormalLoad
Restored
Load Added in Previous
Tier (Now Normal)
TotalCircuit Load
with Cold Load Effect
Total NormalCircuit
Load Restored
Tler 1
Tler 2
Tler 3
4.33
2.83
1.85
0.00
4.33
7.15
12.5
12.5
12.5
4.33
7.15
9.00
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ldaho Power Company Northem Wood RiwrValley Local Backup Elecfical Supply Report
Thrtl 1.00 9.00 11.9 10.00
It would be a minimum of an hour from the time when load was rostored to Tier I before Tier 4
could be added to the distribution circuit. In that time, the temperature would drop below fte
minimum te,mperature thneshold of 55"F.
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ldaho Pouer Company Northem Wood River Valley Local Backup Electrical Supply Report
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Page A11
Appendix B
Power Usage Distribution 3Em.
AnD OOnPComparry
Power Usage Distribution
Ketchum, ldaho, Area
Ketchum Energy
Resilience Team
November 2016
@ 2016 Idaho Power
Study Report V.2
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
TeaLe oF CoNTENTS
Table of Contents
List of Figures
List of Appendices
Power Usage Distibution
Background
Method l: Temperature Based Energy Usage
Method 2: Population and Occupancy Based Energy Usage.
Method 3: EnergyUsage Based Calculations
Results from the Three Methods....
Using the Results
Conclusions
References
Review/Revision History......
Figure 2
Peak electrical demand before load reduction
.t
.i
.i
.1
.1
.l
.2
.3
.4
Application: Heat Load Reduction............ ...........4
,.4
..5
..5
LsT oF FTGURES
Figure 1
Hourly Energy Consumption ................4
Figure 3
Peak electrical demand after load reduction ........................5
Appendix B.A
Method I Calculations 7
LIsr oF APPENDIcES
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Northem Wood RirerValley Local Backup Electrical Supply Report ldaho PovwrCompany
Appendix B.B
Method2 Calculations
AppendixB.C
Method 3 Calculations
Appendix B.D
Application Calculations..................
10
l3
l4
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ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Powen Usece DrsrRreurloN
This report describes three independent methods that are used to estimate the heating load
percentage of the peak load during the winter peak. The purpose of the study is to estimate the
potential electric load reduction associated with heating that can be achieved during the winter
peak period.
Background
A multistakeholder team, including the City of Ketchum, Sun Valley Company, Idaho Power,
and NRG, attended the Rocky Mountain Institute's Electricity Innovation Lab (e-Lab) during
March of 2015. The team is exploring the feasibility of reducing electrical demand during an
emergency event (e.g. loss of transmission) and supplying the electrical demand with local
generation. To that end, this report breaks down the electricity demand during externe winter
conditions (peak demand energy) into usage categories. With that breakdown, the benefit of
various demand response programs, such as lowering thennostat settings can be estimated.
There are different ways to look at electricity usage: energy (the amount of electricity consumed
over time) and demand (the amount of electricity being used at a given time). This calculations
in this study use both annual electrical energy and electrical peak demand. Annual energy is the
total energy used over the period of one year, and does not include data on the distribution of the
energy usage throughout the year. Elecnical peak demand is based on the time when electricity
usage is at its highest.
This study is focused on estimating the electricity used to support heating during peak demand.
Three independent methods were used to obtain this estimate. Method I uses annual energy and
temperature data to obtain peak demand and estimates the percent of peak demand used for
heating. Method 2 uses average hourly customer energy consumption and area population to
estimate the percent of peak dernand used for heating. Method 3 analyzes daily data to detennine
the usage distribution at peak demand and estimates the percent of peak demand used for heating
from the results.
Once the percent of peak demand used for heating is known, a method can be detemrined to
estimate the percentage of load that can be reduced by lowering thermostats from a comfortable
setting to an emergency setting.
Method 1: Temperature Based Energy Usage
The first method for determining system loading utilizes statistics to determine peak demand
from annual energy usage and temperature data. According to the US Energy Information
Administration (EIA) Residential Energt Consumption Survey,t annual energy usage in the
I Residential Energt Consumption Survey,US Energy tnformation Administration. Retrieved July 13,
201 5 from http://www.eia. eov/consumptior/residential/reports/2009/state_briefs/pdf/co.pdf.
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Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Mountain North region of the United States (which includes Idaho) can be broken down
as follows:
o 50o/o heating
c 29%o appliances
o l9Yo water heating
o 2o/o air conditioning (AC)
The EIA survey is for energy in general. This study focuses on electric energy only.
The breakdown of loads during the winter peak can be estimated using temperature data.
Daily temperature values were used to calculate the number of Heating Degree Days (HDD) or
Cooling Degree Days (CDD). One HDD (or CDD) represents a need to raise (or lower) the
inside temperature one degree on that day. Days with a small HDD (under 20) were not
considered to have a significant portion of energy dedicated to heating. This resulted in a total of
161 days during the year where heating was considered to be a significant portion of energy
usage. Assigning all of the heating energy to those 16l days yields cold weather energy ratios.
The base household load (water heaters, appliances, etc.) are considered to be consistent from
season to season. Based on the percentages above, the amount of energy used for heating, hot
water heaters, appliances and lighting during the cold weather period considered can be
calculated.
See Appendix A for these calculations.
With this method, winter loading was estimated to be:
o 70.25Yo heating
o I7.97o/o appliances
o Il.77o/o water heating
o 0o/o air conditioning (AC)
Method 2: Population and Occupancy Based Energy Usage
The second method is based upon average hourly customer energy consumption and area
population. One consideration to take into account is the large number of cabins and non-
permanent residences. In order to more accurately determine the division of energy usage, the
area occupancy must first be determined.
The ratio of population in Ketchum and Sun Valley, relative to all cities and towns within Blaine
County is 27 .4%. Assuming a proportional amount of people reside near towns, but not within
city limits, the total permanent residences within the study area can be calculated.
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ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
The average household size in Ketchum is 1.88 people. In Sun Valley it is 1.95, and in Blaine
Co. as a whole it is 2.40. Comparing the number of permanent residences, as determined above,
to the number of IPC meters in the same area, the number of vacation homes can be determined.
The occupancy rate of vacation homes is assumed to be the same as the occupancy rate of hotel
rooms and cabins from rental agencies. Adding the number of permanent residents to the number
of temporary residents gives an approximation of the occupancy for any given month.
The vacant homes are assumed to have base loads of heating and water heating, but no appliance
or AC usage. The number of vacant homes is the difference between number of residential IPC
customers and the number of occupied homes in the area. Along with the number of occupants
present, the extreme day kWh usage data can then be used to calculate the amount of load for
different times of the year. Comparing the peak day kWh average to a typical summer day, an
approximation for heat loading can be made by assuming that loading (other than heat) is the
same for both days. The difference between the two energy usages is the amount of heat energy
being used, which can be used to find the percentage of energy used for heating.
See Appendix B for these calculations.
Based on occupancy data, and2014 power usage statistics, the percentage of electrical demand at
peak that is due to heat load is approximately 69.32%.
Method 3: Energy Usage Based Calculations
Seasonal variations in energy usage and knowledge of the area can give some measure of how
energy is used. The area of study is a winter peaking area, with much larger load demand in the
colder months. A load duration curve is shown in Figure l. The Ketchum and Elkhorn energy
usage is measured hourly, and then sorted from highest (winter peak load) to lowest. Using the
calculations in Method l,16l days of the year (44.llo/o) are considered cold weather, which
leaves 55.89% of days as non-heating days. Therefore, the points between 0o/o and 44.llo/o are
considered to have occurred during heating periods, and any between 44.11% and 100%
occurred during non-heating periods.
Power Usage Curve
-Total
MW
70.0
60.0
s0.0
40.0
30.0
20.0
10.0
0.0
Percent LOqA 20% 30% Aoe/o 50% 60eh ?io/o BOe/" 90o/o
Page 83l22t W. ldaho St. (83702)
PO. Box 70
Boi*, lD 83707
Northern Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Figure I
Hourly Energy Consumption
The estimated non-heating load was determined from the load duration curve. This value was
summed with other known non-heating loads that occur during winter peak conditions. This
totals approximately 23.0 MW. The difference between this sum and the total load was
detennined to be heating load. A peak demand heating contribution percentage was then
calculated.
See Appendix C for these calculations.
During the periods heating is used, 45.0% of the total energy is used to heat buildings. The
heating load represents about 61.4o/o of the total peak electrical demand.
Results from the Three Methods
For the Ketchum and Sun Valley area, heating load for homes is approximately 45o/o of total load
during the majority of the winter peak with the percentage of peak elechical dernand for heating
being:
Method 1
Method 2
Method 3
70.25o/o
69.320/o
61.4Yo
All three independently derived methods resulted in similar results. Method 3, which is based on
actual measured electrical usage data will be used in the heat load reduction application.
ApplrcATroN: HEAT Lono Reoucnoru
Using the Results
A method for determining the heat load of a home based on indoor and outdoor temperature was
determined in the report "Property Protection Analysis Report" (PPAR).2 This method can be
used to determine the percentage of heating load that can be reduced by lowering thermostats
from a comfortable setting to an emergency setting.
On an extreme winter day, using the assumptions and methodology contained in the PPAR, it
takes 20.32 kWh to heat a home to 70 degrees, compared to the 16.97 kwh required to heat the
home to 55 degrees. There is a16.50/o reduction in heat load usage.
Taking the peak demand in the Ketchum/Sun Valley area, less the non-heating load, we can then
calculate the reduced heating load. Using that value, the energy savings, or net reduction can be
2 Property Protection Analysis Report,Jared Hansen. Idaho Power Company. October 2016.
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ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
calculated as well. Reducing the thermostat setting from 70 degrees to 55 degrees can result in a
peak electrical load reduction of l0.l%.
See Appendix D for these calculations.
Gonclusions
It is possible to reduce the demand in the area by a maximum of l0.l% with a reduction in
thermostat settings on an extreme winter day.
The peak demand breakdown by percentage contribution before and after energy reduction has
been determined:
Figure 2
Peak electricaldemand before load reduction
Figure 3
Peak electrical demand after load reduction
References
Vtsitor and Room Night Estimates March 2015, Visit Sun Valley. Provided by Aly Swindly
([e-mail]) Retrieved May 6, 20 I 5.
Daily Temperature Values, Weather Underground. Retrieved August 13, 2015 from
htp://www.wunderground.com/tristory/airport/KsuN/2014/l/l/CustomHistory.htrnl?day
end:3 I &monthend: I 2&yearend: 20 I 4 &req_city:&req_state:&req_statename:&reqdb.
zip:&reqdb.magic:&reqdb. wmo:
Degree Day Data. Velma, Vilnis. Degree Days Direct Limited. Retrieved August 6,2015 from
htp : //www.vesma. com/ddd/ddcalcs. htm
l22l W. ld.ho Sr. 6370:l)
P.O. Box 70
Boir.. lD 81707
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Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
ReviedRevision History
This document has been approved and revised according to the revision history rworded below.
Revlew Date Revislons
wt14t2015
10t27t2016
1'v02r2016
lnitiallssue,
Revised fur m-issue.
Add laqe customer load b non{eating lod.
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ldaho Power Company Northern Wood River Valley Local Backup Electrical Supply Report
Appendix B.A
Method 1 Calculations
Temperature Based Energy Usage Galculation
The first method for detemrining system loading utilizes statistics to determine peak demand
from annual energy usage and temperature data. According to the US Energy Information
Administration (EIA) Residential Energt Consumption Survey,s annual energy usage in the
Mountain North region of the United States (which includes Idaho) can be broken down as
follows:
50% heating
29%o appliances
l9o/o water heating
2o/o at conditioning (AC)
The EIA survey is for energy in general. This study focuses on electric energy only
The following calculations determine the ratio based on whole year energy use then calculates a
factor to convert them to HDD seasonal ratios.
Daily temperature values were used to calculate the number of Heating Degree Days (HDD) or
Cooling Degree Days (CDD).4 One HDD (or CDD) represents a need to raise (or lower) the
inside temperature one degree on that day. Days with a small HDD (under 20) were not
considered to have a significant portion of energy dedicated to heating. This resulted in a total of
161 days during the year where heating was considered to be a significant portion of energy
usage. Assigning all of the heating energy to those 16l days yields cold weather energy ratios.
3 Residential Energt Consumption Survey, US Energy lnformation Administration. Retrieved July 13,
2015 from http://www.eia.eoviconsurnption/residential/reports/2009/state_briefs/pdflco.pdf.
a Degree Day Data. Velma, Vilnis. Degree Days Direct Limited. Retrieved August 6, 2015 from
http://www.vesma,com/ddd/ddcalcs.htnr.
l22l W, ldaho St. (83702)
PO.8ox 70
Boisc, lD 83707
o
a
o
a
Page 87
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Table 1
Acronyms used in temperature based energy usager daily heating calculations
Variable Name Meaning
HDD
SWR
SAR
\ A/R
YAR
NWP
NAP
STR
HR
NHR
Heating degree days
Seasonal water heater energy usage ratio
Seasonal appliances energy usage ratio
Yearly water heater energy usage ratio
Yearly appliance energy usage ratio
New water heating energy usee percentage ratio
New appliance energy usage peroentage ratio
Scaling factor to convert yearly energy usage to cold weather energy usage
Heating Energy Ratio
New adjusted heat energy ratio
The base household load (water heaters, appliances, etc.) are considered to be consistent from
season to season. Based on the percentages above, the amount of energy used by hot water
heaters during the cold weather period considered was calculated.
HDDSWR=YWR*-365 days
t6LSWR=L9o/o*ffi=8.38o/o
The amount of energy used by appliances and lighting was also calculated.
HDD
^SAR: YAR*
-
365 days
767
^SAR = 29o/o*m= L2.79o/o
A percentage of energy used during the cold weather period relative to the year was calculated to
derive a scaling factor.
STR=SWR+SAR+HR
SIR = 8.38%o * 12.79o/o * 50o/o = 7 L.L7o/o = 0.7 L17
SWRNWP =M'
Page 88
ldaho Power Company Norhem Wood Riwr Valby Local Bmkup Elmfical Supply Roport
NwP = 8.38% .h= Lt.7796
s/lRMP=m
NAP = t2.79vo. # = t7.97vs
HRIVIIR = srR
!IVIfR = 5oct66=74.259fr
Withthis m€&oq wint€r loading was estimatod tobe70.257o heating, 17.97o/s rypliances,
and I 1.7 7 % water heating.
tlrt YY. Edrtt laill,[o.tqr0
loh.Drerg,
Page B9
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Appendix B.B
Method 2 Calculations
Occupancy Galculation
The ratio of population in Ketchum and Sun Valley, relative to all cities and towns within Blaine
County is27.4o/o. Assuming a proportional amount of people reside near towns, but not within
city limits, the total permanent residences within the service area can be calculated.
Table 2
Acronyms used for occupancy calculations
Variable Name Meaning
PPT
KCHM
SV
Towns
NPT
TR
PRP
rPc
NPOR
cRo
MOR
VH
EPVH
EPOR
ERIOVH
ESC]OVH
ELC[( /H
EVH
Percentage of population in Ketchum and Sun Valley
The population of the town Ketchum
The population of the town of Sun Valley
The population of all towns in Blaine County
Total population near, but not in, Ketchum or Sun Valley
Temporary residences (1.E. Rentals, vacation homes)
Permanent resident population in or near Ketchum or Sun Valley
ldaho Power customer points
Number of permanently occupied residences
Current residences occupied
Monthly Occupancy Rate
Vacant homes or residences
Number of vacant homes at energy peak
Energy peak occupancy rate
Extreme year residential Kilowatt hours (kWh)
Extreme year small commercial customer kWh
Extreme year large commercial customer kWh
Energy use in vacant homes (not appliances, lighting or AC)
KCHM + SVPPT --
--L t owns
2706 + 1408
PPT = 15019 -- 27.390/o
Page B10
NPT = @PD * (Blaine Co Pop -lrowns)
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
NPT -- (27.39o/o) * (21376 - 15019) = L74L
In Ketchum, the average household size is 1.88, in Sun Valley, 1.95, and in Blaine Co. as a
whole,2.40.
NpoR = NPT/2.+o+KCHV11.88 + t /r.rr= zBBl
Comparing the number of permanent residences to number of IPC meters in the same areq the
number of vacation homes can be determined.
TR = IPC - NPOR = 7575 - 2887 = 4688
The occupancy rate of vacation homes is assumed to be the same as the occupancy rate of hotel
rooms and cabins from rental agencies. Adding the number of permanent residents to the number
of temporary residents gives an approximation of the occupancy for any given month.
CRO=NPOR+(MOR*IR)
CR0Qanuary 20L4) = 2887 * (420/o * 4588) = 4856
The vacant homes are assumed to have base loads of heating and water heating, but no appliance
or AC usage. The number of vacant homes is the difference between number of residential lPC
customers and the number of occupied homes in the area.
VH = IPC - CRO = 7575 - 4856 = 2719
Loading Calculations Based on Occupancy
Along with the number of occupants present, the extreme day kWh usage data can then be used
to calculate the amount of load for different times of the year. Comparing the peak day kWh
average to a tlpical srunmer day, an approximation for heat loading can be made by assuming
that loading (other than heat) is the same for both days. For the peak day, the calculation is as
follows:
Peak Load = ERKWH * IEPOR * EVHo/o * EPVHI
+ ESCKWH * (#Small Customers) + ELCKWI{ * (Large Customers)
Peak Load : (3.92kwh) * [5372 * 83o/o * 22037 + (L.ggkwh * 7 67) + (13.67 kwh * 838)
= Peak Load = 4L207.7t
On a normal summer day, where there would be no heating or AC load, the calculation is:
CRO VHLoadtng = ERKWH *(cRo II EP?R)
* (EVH o/o) *
PVH
Page Bl 1l22l W. ldrho St. (E3702)
P.O. Bor 70
Boir., lD 83707
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
+ ESCKWH ,* (# Small Customers) + ELCKWII * (#Large Customers)
= 72643.37 kwh
The difference between the two e,lrergy usages is the arnount of heat energy being used, which
can be used to find the percentage of energy used for heating:
Loading=(.91kWh)-W,,,,,+(saz,"ffi)l*o.u,*767+7.75*838
Peak Usage Day - Simtlar DayHeat energy =
Heat Energy Percentage =W = 69.320/o
Based on occupancy data, and20l4 power usage statistics, the percentage of demand at peak that
is due to heat load is 69.320/o.
PageBl2
ldaho Power Com Northern Wood River Val Local Backup Electrical Report
Appendix B.C
Method 3 Calculations
Energy Usage Based Calculations
The estimated non-heating load was determined from the load duration curve. This value was
summed with other known non-heating loads that occur during winter peak conditions. The
difference between this sum and the total load was determined to be heating load. A heating
contribution percentage was then calculated.
H e ating Lo ad P er centag e
Total Energy durtng Heating -Total Energy of non heattng loads
Total Energy during Heattng
L22850.4 - (67620.0) __ 45.0VoColdweather pertod heattng load = lZZgSU4
Peak Demand, heattng contrtbution
Peak Demand dtrbry Heating - (surn of non heating loads durtng Peak Demand)
Peok Demand durtng Heattng
Peak Demand. heattng contribution = W = 6L.4Vo
During the periods heating is used, approximately 45.0o/o of the total energy is used to heat
buildings. The heating load is 61.4o/o of the peak demand.
l22l W. ld.ho St. (83702)
P.O. lox 70
8oir., lD 83707
Page B13
Northern Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Appendix B.D
Application Calculations
Heat Load Reduction
On an extreme winter day, the PPAR determined that it takes 20.32 kWh to heat an average
home to 70 degrees, compared to the 16.97 kwh required to heat the same home to 55 degrees.
There is a 16.5% reduction in heat load usage.
20.32 kwh - L6.97 kwhReductton = @ = L6.5o/o
Taking the peak demand in the Ketchum/Sun Valley are4 less the summed non-heating load, we
can then calculate the reduced heating load. Using that value, the energy ssyings, or net
reduction can be calculated as well.
Heat Load = Peak Load * Heating Percentage
Heat Load = 59.6 MW * 67.40/o = 36.6 MW
Other Loads = Peak Load - Heat Load
Other Loads = 59.6 MW -36.6 MW = 23.0 MW
Reduced Heat Load = Heat Load * (1- Reductton)
Reduced Heat Load = 36.6* (1 - L6.So/o) = 36.6* ( 83.57o) = 30.6 MW
Reduced Peak Load = Reduced Heat Load * Other Loods = 30.6MW + 23.0 MW = 53.6 MW
Load Reductton = Heat Load * Reductton = 36.6 MW * 16.50/o = 6.0 MW
Load Reductton 6.0 MWTotalPeakLoadReducttonPercentag,=W=m=l0.Lo/o
Page B14
3EHH.
AnIOTCOPPConFw
Appendix C
City of Ketchum Solar Generation Assessment
August I l, 2015
Ketchum e-Lab Team Members
Subject: City of Ketchum Solar Generation Assessment
Dear e-Lab Team Member:
I directed mernbers of the Idaho Power Customer Operations Planning staffto undertake a high-level
assessment of the photovoltaic resource within the city limits of Ketchum, Idaho. In order to estimate this
solar photovoltaic (PV) resource capacity, Idaho Power developed a sampling technique to approximate
the amount of residential and commercial roof area suitable for photovoltaic installation. This sampling is
based on the existing land use which is comprised of 52.87o/o residential, 7 .85% commercial and 39.28%o
undeveloped area. A sample area of 0.28 squaxe miles, which matched the city land use, was selected as
shown in Figure l. The roof area within the area was computed.
This available area was reduced by roof geometry, near shading, orientation, and other considerations
following guidelines outlined by the National Renewable Energy Laboratory NREL)
(http:/iwww.nrel.sov/docs/fyl4ostii60593.pd0 to determine the roof area suitable for PV installation.
This NREL document identifies 25% of residential and 60% of commercial roof area is suitable for PV
installation. The area was further reduced by 50%o to match the average net-metering installation in the
area. This resultant roof area was scaled to the area of the Ketchum City limits and produced 112,578 m2
of PV suitable roof area.
Figure l: Sample Area
l22l W. ldtho 5t. G370:l)
P.O. Bor 70
Bok . lD83707
Page Cl
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
An estimate of the daily energy produced by the suitable roof area was calculated using the solar intensity
data from the NREL PVWatts progrcm (http://pvwatts.nrel.eov/). Standard efficiencies for the PV panels
and inverter were applied , 16%o and 95 .60/o respectively.
During December and January, there are only eight hours of sun light in the Ketchum area which
produces an average daily solar radiation of 2.54 kWlr/m2 and 1.64 kwh/m'z, respectively, as reported in
the typical meteorological year (TMY3) data from NREL for the Hailey, ID area. This solar irradiance,
estimated roof area and the efficiencies result in Decernber and January daily generation ranging froml0-
30 MWh. The city's daily load during this time period ranges from 300-790 MWh.
Figure 2 provides a winter example of the PVWatts data for December 23.T\e average solar irradiance
for that day is 1.27 kWh/m'z. This irradiance coupled with estimated roof PV coverage would produce
21.64 MWh of PV Generation. In comparison, the December 23,2014 Ketchum city customer
consumption was 519.75 MWh.
12123120t4 Load and Estimated PV Generation
t!0
35
30
25
!zo
15
10
5
0
I 2 3 4 5 5 7 8 9 10111213t4 15161718192021222324
Hour
r Load t2123114 I Estimated PV Generation
Figure 2:Load and Estimated PV Generation
Figure 3 provides a summer example of ttre PVWatts data for June 2l't. The average solar irradiance for
that day is 7 .71 kWh/m2. This irradiance coupled with estimated roof PV coverage would produce 131.23
MWh of PV Generation. On this day in 20l4,the Ketchum city customer consumption was 187.35 MWh.
Page C2
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
OG I zll 2Ot4 Load and Estlmated PV Generation
tlo
35
30
23
i,,
15
10
5
0
123456789 10 11 1:2 t3 14 15 t6 t7 18 19 20 2t 22 Z? 24
Hour
r Load 6l2Ll14 I Estimated PV Generation
Figure 3:6/21/2014 Load and Estimated PV Generation
In conclusion, the estimated roof PV generation will not produce sufficient enerry to meet the elechical
consumption by customers within the city of Ketchum. The winter generation is not able to support the
property protection energy level and the summer output cannot meet the sunmer energy requirement.
Additional resources will be required to meet the service levels above critical life safety (police, fire and
hospital).
You are welcome to contact me at 208-388-2701or dangell@idahopower if you have questions or wish to
discuss this analysis.
Sincerely
David M Angell
Manager, Customer Operations Planning
lr2l W. ld.ho St. G3r02)
P,O. Box 70
Bok , lD83707
Page C3
Nor$6m Wood MverValley Local Bsckup Eleefiioal Supply Report ldaho Fou€r Company
This pagn left blank intentionally.
Page C4
ldaho Power Company Northem Wood River Valley Local Backup Electrical Supply Report
Appendix D (This appendix has been edited to conect an error in the original report. See details below.)
Microgrid Study Results
Diesel Generator results
The results for a one-day transmission line outage with diesel engine generators providing
backup power are shown in Tables I through 5.
Table I Energy Provided
Component Production (kwh/yr) Fraction (ok)
Table 2 Diesel Generator Parameters
Quantity Value
Generator
Grid Purchases
Total
Hours of operation
Number of star*
Fixed generation cost
Marginal generation cost
Electrical production
Mean electrical output
Min. electrical output
Max electrical output
Fuel consumption
S p e cifi c fu e I c o n su m pti o n
Fuel energy input
Mean electrical eficiency
1,150,000
223,6LL,53L
224,76L,540
L
99
100
Units
Hrs/yr
Starts/yr
S/hr
s/kwh
kWh/yr
KW
KW
KW
tlvr
L/kwh
kWh/yr
%o
24
I
4,677
0.13
1,150,000
51,095
43,938
58,505
302,597
o.26
2,977,557
39
Page Dl
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Table 3 Diesel Generator Emissions
Pollutant Emissions Units
Carbon dioxide
Carbon monoxide
Unburned hydrocarbons
Particulate matter
Sulfur dioxide
Nitrogen oxides
t42,LLg,326
L,967
2L8
L48
6L4,296
3L7,t90
Kelvr
Kelyr
Kelyr
Kelvr
Kglvr
Kelyr
Table 4 Diesel Generator Capital cost sensitivity analysis
Capital Cost Total Copital Cost($/t<W1 (Millions of dollors)
Ssoo
s7s0
S1,ooo
S1,2so
s1,500
S33,4oo,ooo
s50,100,000
s66,goo,ooo
s83,500,000
s100,200,000
Table 5 Diesel Fuel Cost Sensitivity Analysis
Fuel price Totnl fuel cost
($/sat)
$z.oo
52.2s
s2.so
52.7s
s3.00
s159,800
S179,700
$199,700
s219,700
5239,600
Table 5 was computed with a l-day outage during the peak months.
Page D2
ldaho Power Com Northern Wood River Valley Local Backup Electrical Supply Report
Gas Turbine Results
The results for a one-day transmission line outage with gas combustion turbines providing
backup power are shown in tables 6 to 10.
Table 6 Energy Provided by Gas Turbine
Component Production Fraction(kwh/yr) ('/o)
Generotor 1,150,000 1
Grid Purchases 223,6L1,53L
Total 224,76t,540
99
100
Table 7 Gas Turbine Parameters
Quantity Value
Hours of operation
Number of star*
Fixed generation cost
Marginal generation
cost
Electrical production
Mean electrical output
Min. electricol output
Max electrical output
Fuel consumption
Specific fuel
consumption
Fuel energy input
Mean electrical
fficiency
24
1
2,8O2
0.02
1,150,000
51,095
43,938
58,506
333,503
o.29
3,293,338
35
Units
Hrs/yr
Starts/yr
S/hr
s/kwh
kWh/yr
KW
kw
KW
m3lyr
m3/kWh
kWh/yr
%
Page D3
Northem Wood River Valley Local Backup Electrical Supply Report ldaho Power Company
Table 8 Gas Turbine Emissions
Pollutant Emissions
Carbon dioxide
Carbon monoxide
Unburned
hydrocarbons
Particulate matter
Sulfur dioxide
Nitrogen oxides
141,958,690
657
0
0
6t4,434
300,056
Units
Kelvr
Kelvr
Kelvr
Kglyr
Kglyr
Kclvr
Table 9 Gas Turbine Capital Cost Sensitivity Analysis
Capital Cost Total Capital Cost
($/kw
sTso
S1,125
$1,soo
S1,875
s2,250
s4g,g00,o0o
s73,100,000
s97,500,000
s121,900,000
S146,3oo,ooo
Table 10 Natural Gas Cost Sensitivity Analysis
Fuel price Total fuel cost
($/ms1
$0.07s
so.10
s0.124
so.1s
So.17s
S25,ooo
S33,+oo
541,4oo
S50,ooo
S58,coo
Page D4
kldruFq.{nCryrsantr t{or*.unW,ood RfrEr \#alM lM 6ffim Elacrtioal Srpply Ropdt
B ry Bpbm Rreults
Ttc effqteriry &Bllgis fio 6o Bdoe,of &E bettcry ftr a uoday tr-msdsgior lio6 qffigp s'ith &e
wo of FV plue bamryb povido hcJory powcr ia &onn in able I 1.
Tcbls lf &ffir$ eod SGnd&t|ty,lnitydf
Battay Price ($/kMh) Toul Cost
$*ao $sg ,00o
$lJr!ffi $L5l5rtDoo;om
I rfHs Gost 0lr@s ffi86, mls€fied h fu rrrgin"l rpptrt
Feoa D6
Northem Wood River Valley Local Backup Electrical Supply Report ldaho PourcrCompany
This page leftblank intentionally
Page D6
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWERCOMPANY
REQUEST NO. 13
ATTACHMENT 1
<rm"
Anlo coRPcomFny
DONOVAN E. WALKER
Lead Gounsel
[e-mail]
October 7,2020
Ronald Williams
Williams Bradbury, P.C.
P.O. Box 388
Boise, lD 83701
[e-mail]
VIA ELECTRONIC MAIL ONLY
Re: ldaho Power Wood River - Ketchum Transmission Line
Dear Ron:
This is a follow up on ldaho Power's Wood River-Ketchum 138kV transmission line
("Transmission Line") project. ldaho Power appreciated the opportunity to participate in the
County's public meetings on the Transmission Line project on September 3, September 10, and
September 21, 2020. We believe the public has had a good opportunity to comment on the
project. Based on the public meeting discussions and the pressing schedule for the
Transmission Line, ldaho Power is willing to move forward with the Surcharge Option for the
projectl.
\Mile the public comments and stakeholder discussions at the County's public meetings
have been wide-ranging, there appears to be little public support for the County raising the $38
million estimated cost to bury the Transmission Line south of Elkhorn Road. The County
Commissioners and public raised concerns with the LID mechanism (not applicable in cities, 5-
acre exemption) and there appeared to be little support for a two-year levy (requiring a majority
vote by county residents) or long-term levy (requiring a 213 vote). Even with respect to partial
Transmission Line burials near residential developments, the residential developments did not
indicate a desire to provide separate funding for such burials.
Based on comments received and questions asked during the public meetings, ldaho Power
would like to respond to two issues: (1) Consideration of alternatives and (2) ldaho Power's
position on the 3 percent surcharge.
Consideration of Alternatives
The County received a number of comments at its public meetings discussing the
possible use of alternative energy sources to provide backup power to the north valley in place
I The original Surcharge Option proposes burying the existing distribution lines along the Transmission
Line route and burying the portion of the Transmission Line between Elkhorn Road and South Hospital
Drive, based on funding from a 3 percent surcharge for approximately 20 years on all ldaho Power
customers in Blaine County.
l22l W. ldaho 5t. (83702)
P.O. Box 70
Boir., lD 83707
Ronald Williams
October 7,2020
Page 2 of 4
of the Transmission Line. ldaho Power has extensively reviewed this issue and there are no
alternative energy options that would provide the necessary back-up power to the north valley at
an acceptable price. Attached is a copy of the "Northern Wood River Valley-Local Backup
Electrical Supply Report" from November 2016 ("Report"), which ldaho Power prepared with
independent technical review and feedback from the ldaho National Laboratory (with more than
1,000 megawatts of hybrid power, solar, and wind energy systems deployed at Department of
Defense and industry/utility sites around the world). The Report was prepared in connection with
ldaho Power's comprehensive review of potential alternate energy resources to serve the north
valley with the Wood River Electric Plan Community Advisory Committee, the Wood River
Renewable Energy Working Group, and the Ketchum Energy Advisory Committee.
The Report analyzed diesel generation, natural gas generation and solar generation as
potential backup power sources, after determining that wind generation, geothermal generation
and biomass generation were not viable alternatives for the Wood River valley-which remains
the case today. The installation costs and the annual maintenance costs for the three backup
energy sources analyzed in the Report would be significantly higher than the installation and
maintenance costs for the Project: Diesel Engine ($57 million/$1 million), Gas Turbine ($101
million/$O.455 million) and PV plus Battery Storage ($gZa million/$3.45 million).
Diesel Engine and Gas Turbine technologies have not changed significantly since 2016
and remain substantially more expensive than the Transmission Line. Battery Storage
technologies have advanced since 2016, but still cannot cost-effectively meet the electrical
demand of the north valley. The Report analyzes a combined solar photovoltaic ("P\f) and
battery energy storage system with 50 MW of battery generation added to the Ketchum
Substation and 15 MW added to the Elkhom Substation, with the batteries sized to meet energy
needs of the north valley for only one-day outage. The total installation cost of this system is
estimated at $924 million in the Report, plus ongoing O&M costs of $3,450,000 per year. Even
if one assumes a battery system alone (without solar PV generation) with a reduced capital cost
of $350/kWh2, the estimated total installation cost of the battery system would be $429 million.
The Transmission Line cost is far lower and would be able to meet the north valley's total
energy needs on a continuous basis, rather than for just one day, and will allow ldaho Power to
reconstruct the existing transmission line without intenuption to the north valley. As ldaho
Power has emphasized in the past, an outage on the existing transmission line could potentially
last for a week or more, depending on the severity of damage to the line and the accessibility to
the line in rugged terrain and potentially extreme weather conditions.
ldaho Power filed the Report with the ldaho Public Utilities Commission ("|PUC") as part
of its application for Certificate of Public Convenience and Necessity ('CPCN") for the
Transmission Line. Based on the Report and the other evidence submitted at the CPCN
proceeding, the IPUC concluded that alternative power sources were not effective alternatives
to the Transmission Line, and that the Transmission Line is needed to provide backup power to
the north Wood River valley. The County's Chief Deputy Prosecutor, Tim Graves, emphasized
this point at the County's recent public meetings, stating that the IPUC has already determined
the need and necessity for the Transmission Line in its 2017 order approving the Transmission
Line CPCN.
Given the urgency of the Transmission Line project, ldaho Power is prepared to seek the
required legal approvals to move forward with the Surcharge Option. ldaho Power provided the
Surcharge Option in response to the County's Transmission Line burial proposals earlier this
2 This figure reflects the capital cost of a flow battery from Lazard's 2019 Levelized Cost of Storage report.
Ronald Williams
October 7,2020
Page 3 of 4
year, and ldaho Power is not aware of any other burial option south of Elkhorn Road with a
viable funding source, leaving the Surcharge Option as the only practical alternative to ldaho
Power's base Transmission Line plan approved by the IPUC. Several stakeholders or their
representatives indicated overal! support for the Surcharge Option at the County's September
21, 2020 public meeting.
3 Percent Surcharse Ootion
ldaho Power is generally opposed to any form of on-bill surcharge to fund third-party
requested undergrounding costs beyond that which is provided for through state authorized
franchise fees. However, in an effort to reach a compromise that would allow for the
Transmission Line project to move fonrvard, the company is willing to apply an on-bill surcharge
for ungrounding costs in this instance not to exceed 3 percent of billed revenue by customer
segment. This 3 percent threshold is consistent with the current 3 percent €p on franchise fee
collection by city. lf implemented, many city residents within Blaine County (Bellevue, Hailey,
Ketchum, and Sun Valley) would pay a total of 6 percent of their ldaho Power bills toward costs
not required for the provision of safe, reliable electric service. ldaho Power strives to keep prices
low for its customers and the surcharge envisioned in this letter will appear to most customers
as an ldaho Power price increase. Therefore, ldaho Power wishes to limit that increase to no
more than 3 percent in this instance.
ln a show of good faith, ldaho Power has refined the Surcharge Option and determined
that the company can provide additional undergrounding-from South Hospital Drive to Owl
Rock Road-while holding the surcharge at 3 percent. The company identified increased
revenues that would cover the projected costs of this additional undergrounding by applying a 1
percent annual growth factor to Blaine County customers' billed revenues. This additional
undergrounding meets the requests of several parties and further positions the Option as the
best pathway forward for Blaine County.
ldaho Power again would like to reiterate that the Surcharge Option is based upon
projected costs. And given the likelihood that projected costs will not perfectly match actual
costs, ldaho Power proposes a reconciliation of surcharge collections against outlays. Such a
reconciliation would determine any over- or under-collection by ldaho Power that would adjust
Blaine County's payback period. ldentified over-collection would reduce the payback period
below 20 years for Blaine County, while any under-collection would extend the payback period
beyond 20 years.
ldaho Power understands that the County may wish to conduct surveys or other public
outreach regarding the Surcharge Option. As explained during the Blaine County Public Meeting
on September 21, ldaho Power is willing to provide references to survey companies and share
lessons learned from our own experiences conducting surveys, but the company will not
conduct or participate in public surveys because the Surcharge Option has been provided by
the company at the County's request.
ln the interest of expediency, ldaho Power suggests a meeting the week of October 19
with representatives of the County, IPUC Staff, and ldaho Power to discuss the applicable
procedural steps. We believe there are severa! procedural options available to obtain the
required legal approval for the Surcharge Option, and would like to discuss those options with
the County and Staff as a possible alternative to ldaho Power's base Transmission Line plan.
Ronald Williams
October 7,2020
Page 4 of 4
As ldaho Power has stated before, the company remains concerned about continued
delays to the project schedule. Each season the project is delayed extends the future in-service
date, prolonging the exposure of the north County and its residents to the ramifications of a
major outage on the existing transmission line.
ldaho Power appreciates Blaine County's ongoing commitment to finding a mutually
agreeable solution, and we look fonlrard to further convercations about a pathway fonrard on
the Surcharge Option.
lf you have any questions about this analysis, please do not hesitate to contact me.
Sincerely
Mzdott<-
Donovan E. Walker
cc:TeriCarlock,ldahoPublicUtilitiesCommission,@
John Hammond, ldaho Public Utilities Commission, [e-mail]
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO. 14
ATTACHMENT 1
TRAIOiISSION LINE STT'DY
SI'RXTET RESEARCH REPORT
NOVEI,IBER 2O2O
OVER,ALL RESI'LTS
QI,ESTION
RIGIIIT DIRECIION
IEROTTG ERACI(
NOT S['RE
NET RIGHT DIRECIION
RIGHT : IIRONG
NONE
ot{E
nrc
THREE
tr.OI'R
FTVEsrx
SEVEN OR IORE TIUES
9t ESTTON
VERT TTTARE
SOMEIfIIAT TTTARE
NOT VERY TIINRE
NOT ST'RE
BARRY ZEPLOWITZ & ASSOCIATES
rO|fAL
I.ET ME BEGIN BY ASKING IF YOU EEEL THINGS IN BIAINE COI'IITY
ARE GENERAI.LY HEADED IN THE RIGHE DIRECTION OR ARE THEY
OFl. ON THE TIRO}IG IR,ACK?
1
2
98
1
2
3
98
t
69
2L
11
{8r
*
206
62
32
300
1{{
3.3:1
QI'ESTION 2. HoIT IIAITY TIUES A TIEEK DO YOU DRN|E EEIIIEEN HAII.EY AND KETCIIT,M?
0
1
2
3
4
5
6
7
t
70
58
a8
32
37
22
7
25
t
23
19
16
11
L2
7
2
8
*t7L
46
11
1
t
75
20
5
1
TOIAL 300
MEAN(N) 230
3. IItsEN DRTVING THROUGH BIATNE COI'NIt, ARE YOU VERY TXIARE,
SOMEIIHAT AI{TRE OR NOT VERY AI{ARE OE' TITE SCENERY BtsrlEEN
HAII.EY AIID KETCIIItr{?
3.2
-l
BARRI ZE9IX//frTTZ T ASSOCIATES
TOTAI. 23O
LL-23-2020 PAGE O\r-1
TRATIMISSION I.INE STT'DY
SURI'EY RESEARCH REPORT
NOVE}IBER 2O2O
O'ERATL RESI'LTS
QrrEsrIoN
VERY IMPORTAI{T
SOMEWHAT II.TPORTAIIE
NOT VERY IUPORTANT
NOT IMPORTAITT AT AIT?
NOT SURE
9UESTION
YES
NO
NOT SI'RE
IIET IES
YES : NO
QI'ESTTON
IES
NO
NOT SURE
NET T'ES
t-ES : NO
4. HoIT II{PORTA}IT IS IT TO YOU TIIAT IIIE SCENERY BEII|EEN HAII.EI
AIID XETCIIUT.{ REIIAIN IINOBSTRUCIED:
1
2
3
4
98
1
2
98
rorAr. 300
5. ARE YOU AIIARE OE THE PT'BI]IC UTILIIT C6AIISSIOI{'S DECISIOII
THAT A REDI'NDAIT I.INE IS NEEDED TO PRO1TIDE ADEOUATE &
RELIABI.E SERVICE EO THE NORTB V}IJ.EY?
*
19rl
55
33
11
7
t
65
18
11I
2
*
195
100
5
t
65
33
2
TOTAI. 3OO
32t
6. E}ID ARE YOU EXXARE OF IDNIO POgIER'S PROPOSAI. BO BUII,D A
REDI'IIDTI{T POTfER MADISMISSION LINE BETWEEN TIIE ST'BSTATION NORMI
OF HAILEY At{D TIIE KETCHItr{ SITBSTAUON?
95
2.OzL
811.8:1
*
189
108
3
t
63
36
1
1
2
98
TOTAI. 3OO
27*
BARRY ZEEI.{NITZ E ASSOCIATES LL-23-2020 PaCE Olr-2
IRA}[riI9SION LINE STUDY
ST'RVEY RESE.ARCH REPORT
NOVEMBER 2O2O
O\IERAI.L RESI'LIS
QI'ESTION
IES
NO
NOT ST'RE
NET YESIES : NO
QT'ESTION
YES
no
NOT ST'RE
ITET YES
YES : NO
7. DID TOU IWorT THAT BIAINE COT'NE, TF ORDERED BY THE PT'BI.IC I'TILITY
coL fisgroN, Mugr ALror rDNIo PoItER so BUrr.D rHE REDIrDAI{T
IRN{SD'ISSION I.INE?
1
2
98
1
2
98
rorAl, 300
-37 -12r1:1.3
8. TIIE IDNIO POTTtsR OVERIIEED TRA}I$fiSSION LINE ITOUI.D RI'N AI.ONG
BIITTERCT'P RD AND HIGIilXAY ?5 TO TTIE T'IIDERGROI'IID COIIDUIT AT
EIJ(HORN RD. XF TTIE TRA}ISO(ISSION LIITE IIERE TO BE UI{DERGROT'IIDED
SOIIIII OF ELI(HOR}I RD,, IIOUI.D YOU BE WILLING TO PAY AT{ ADDITIOTdAL
FEE OR I.E\TY FOR TTIE LINE TO BE I'IIDERCROI'NDED?
t
L25
L62
13
tt2
5rl
4
*
15{
101{5
TOIAL 3OO
531.5:1
t
513{
15
18r
BARRY ZE.PIfrIITZ E ASSOCIATES LL-23-2020 PACE O\r-3
M,a}IMISSION LII{E STUDY
SI'RVEY RESTARCH REPORT
ITO\TEMBER 2O2O(ryERAIL RESI'LTS
QT'ESEION 9. OPIION 1 IIOULD T NDERGIROIrIID TIIE EIIIIRE rRNISIIISSION LINE
ERC[.{ THE WOOD RIVER SITBSIATION NORIB OE HAILEY IO EIfiHOR}I RD
THERE TOI'I.D BE NO NEW OVERHE.AD LIITES OR POI.ES NE.AR HOSPITAT
DRTVE BIXI EXISEING POI.ES AI.ONG BUIIIERCI'P A}ID HXGITTXAY 75
nOIrL,D REIAIN. IIIIS TIOITLD LESSEN fHE IMPACT IO LIE'B ELIGHI
I}ID RESIDEITES PROXIT'ATE TO rlIE L,IIIE. THE COST TK)UI.D BE
$38,151,503 OR $182 PER $500,000 ASSESSED PROPERry VAr.IrE
AT{NI'ATIY FOR 30 IEARS.
[rs THAT SIB,ONGI,Y/SOMSINIIATI
1
2
3
4
98
99
SBONGLY
SOIEIIHAT
SOMEINHAT
gTRONGI,Y
NOT SI'RE
REFUSED
SUPPORI
SUPPORT
OPPOSE
OPPOSE
*
55
99
{1
60
a3
2
t
19
33
1{
20
1rl
TOIAL 3OO
SUPPORT
OPPOSE
NET SUPPORT
SI,PPORT : OPPOSE
15{
101
53
1.5:1
52r
3rlt
18t
BARRY ZEEI.ffiITZ 6 ASSOCIATES \L-23-2020 PAGE O17-l
IN,ANMISSION LINE STT'DY
ST'R\IEY RESE,ARCH REPORT
IIo\TEMBER 2020
OVERAI.L RESI'LTS
QrrEsIIoN 10. OPrION 2ITOI'ID I'NDERG,ROI'IID THE EXXSIING LINES ALONG TIIE EIITIRE
ROI'TE END REPI.ACE I'ITII A TRA}{SO{ISSION LINE NORn TO SOI,inI OEIIIE HOSPITAI. THE POI.ES A}TD OVERIIEAD LINES IIOI'ID STAY @NERAI.LY
THE TIA}IE HEIGIIE AIID REDUCE rIIE M'MBER OF LINES. NO NETT OVERIIEAD
IRn}I${ISSTON LINES TIOI'ID EE BUILT AIONG HOSPIIAL DR., THE BINE
PAIll, OR EIIE MTLIIPLE IOBILE HOME OR APARD'EIIE CO,IPLEXES. II
NOUI.D I.ESSEN THE IMPACT TO LII'E ELIGTIT EIID RESIDENTS PROXIT{}TEro rHE NEW LrNE AT A COST OF $8.{ tGr.r.rON. A EIAT INOIWELY RAIE
FOR: RESIDENEIAL CtgTOtlERS IIOULD PAY $3.57 PER tlON'lB,
NON-RESIDEDTTTAL C!STo[GR!! ITOULD PAY $8.{3 PER tprrTrl A}tD
ITNMETERED CUSTO,IER,S ttOUr.D PAY 93.77 PER !!O}{TH.
NOT'I,D YOU SUPPORT OR OPPOSE THIS OPTION 2?
lrs rHAT SIRoNGLY/SOUEITHATI
1.
2.
3.
4.
98.
99.
SMONGI.Y
SOUENHAT
SOMEWHAT
SIRONGLY
NOT SURE
REFT'SED
SI'PBORT
SI'PPORT
OPPOSE
OPPOSE
t
18
38
16
15t2
169
92
77
1.8:1
57*
31r
26*
1
*
55
15{8tLl
36
2
TOrAr 300
SI'PPORT
OPPOSE
NET SI'PPORT
SITPPORT : OPPOSE
BARRY ZEP'TNfrATZ E ASSOCIATES LL-23-2O2O PAGE Olr-5
Its.N{MISSION LINE STT'DY
SI'RVEY RESEARCH REPORT
IIOVEMBER 2O2O
OVERAIL RESULTS
QT'ESTION 11.OPTION 3 WOT'I.D INSTAI.L $IE OVERHEAD TR,A}IST{ISSION I.INES WITH
EXIRA LINES AS PROPOSED BY IDAIIO POWER; 11 M:ILES OF O\TERIIEID
IRAIISITIISSION, DISTRIBII|IION, AllD IIIfLIIY LINES BUILI ALONG
BTIT'IERCUP ROAD, HTGHWAI 75 A}ID A M,AI|SL{I3SION LINE AIPNG
HOSPITAI. DRIVE AI{D TIIE BIKE PAMI BO EI.KHORN RD TIIE O\TERHEID
LINES IIOUI.D DOI'BI,E EROM 3 IO 6, IN N)DITION TO THE EXISTINC
I.E.ASED CABIJE I'INES. THE POI'ES IIOUI'D BE 8 FEET 5 INCHES TO1{ EEET TAIJ.ER TIIA}I TITE EXISTINC I.TNES ATID TEERE TTOT'I.D BE ITO
COST TO COI'Nry RESIDEIITS.IYOT'ID YOU SUPPORT OR OPPOSE THIS OPTION 3?
IIS TITAT STRONGLY/SOMEMIIATI
1.
2.
3.
4.
98.
99.
QI'ESTION
SMONGLY
SOMEIfHAT
SOMEINHAT
STRONCLY
NOT SI'RE
REFI'SED
SUPPORT
SUPPORT
OPPOSE
OPPOSE
*
60
47
56
10{
30
2
t
20
16
19
35
10
107
161-5{1:1.5
36r5{t
-18*
t
34
31
27I
TOTAI. 3OO
SUPPORT
OPPOSE
NET SI'PPORT
SUPPORT : OPPOSE
-l
12. INHICH OF TIIE THREE OPTIONS T HAVE JUST READ DO YOU ST'PPORT
IHE IOST:
OPTION 1, UIIDERGROI llD THE EI{TIRE IRA}ISITIISSION LINE A}tD PAY
WITII A 3O-YEER I.El'T. OPIION 2, I'IIDERGROI'IID P}RT OF TIIE
TR,IIIST.fiSSION LI}IE A}ID PAY A EIAT RATE FOR 20 TEARS. OPIION 3,
BUILD THE M,A}I$(ISSION LINE ABOVE GROT'ITD AT ![O COST FOR
RESTDEIITS.
1.
2.
3.
98.
99.
OPTION 1
OPTION 2
oPttIoN 3
NOT SURE
REEUSED
*
99
91
79
24I
TOTAL 3OO
BARRY ZEPIPWITZ 6 ASSOCIATES LL-23-2020 PAGE OV-6
M,A}IMISSION I.IITE STT'DY
SI'RVEY RESEARCH REPORT
IIo\TEMBER 2020
OVERALL RESI'LTS
QTESTION 13. pr.EASE IELL ME tflrr YOU CHOSE OPTTON 3?
TIIIS OPTION IIOI{'T COST RESIDEIITS }ONEY
INDTFT'ERENT EBOUT HAVING LIIIES IN THE VIE}I
DON' T BELIEI'E NOI'I.D HAI'E POSIITVE IMPACT
DON'T HAVE AlT OPINION AEOIIT TIIE PRO.'EC'T.
EASIER !O I{AITITAIN
NOT SI'RE
TOTAI.
QrrEsrIoN 1{. AGE
t
76
8
5
e
3
3
*
60
7
4
3
3
3
79
1
2
3
4
5
98
-l
1
2
3
4
5
18-3{
35-{9
50-64
65-74
75+
*
46
57
79
72
a6
t
15
19
26
24
15
orrEsrroN 15. GENDER
trtN.E
FEMEI.E
1
2
TOTAL 3OO
f
131
169
TOTAL 3OO
t
44
56
BARRY ZEPI.C,nITZ T ASSOCILTBS LL-23-2020 PAGE Ov-7
IRIII(rSSION LIIE 811DI
StIEITIT RESIARCE AIPORI
NOvEr@R 2020
OVINTIJL BESULES
QESIIOI 16. GTOCR,ADUIC
UTITICOREORTIIED
ItsLIiElrUl
CIREIAAIIlIracB([rgutf \rAr.Iat
gpEglroN 17. cs&L PBoEs
rl8
0
1
2
3I
5
Ir96 3233 1193105 3536 L22L7
300
1
2
I
a2NO
EOET'.
218
rdrrL 300
t
73
27
-l
-
BTNRf,
'EPI.(TI'IE8
E TSSOCILTES tL-23-2020 PICE d7-8
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWERCOMPANY
REQUEST NO. 14
ATTACHMENT 2
B.try hglowlfu e, Acror,tatoc
Blaine County
Survey Research Report
November 2l-23,2020
Summary Analysis
We began our survey by asking respondents if they felt things in Blaine County
are qenerallv headed in the rioht direction or are thev off on the wronq track. 697o said
things were headed in the right direction while a much smaller 21o/o said things were off
on the wrong track. These are very impressive numbers and represents a view that the
county is being well run and residents are comfortable with their government. Wrile we
see a very positive perception of the direction things are headed in the coung, we do
see some slippage (57Yo\ among those who selected Option 3.
We found thatTTo/o of our respondents drove between Hailev and Ketchum an
average of 3.2 every week. Among those who support Option 1,89o/o drove between
Hailey and Ketchum weekly while this dropped to 63% among those who supported
Option 3.
Among those who drive between Hailey and Ketchum,TSo/o said they were very
aware of the scenerv and this climbed to 98o/o among those who drive between the two
cities seven or more times a week.
Two-thirds of our respondents said it was very important that the scenerv
between Hailev and Ketchum remain unobstructed and this climbs higher among those
who travelthis route seven or more times a week and are very aware of the scenery.
Women said it was very important to them by a21% margin over men. Only 15% said it
was not important to them.
1
Residents in Blaine County were well aware (65%) of the Public Utilitv
Commission's decision that a redundant line is needed to provide adequate and reliable
service to the North Valley. This climbed to 74o/o among those who supported Option 3
and to 79% among 65-74 year olds. This dropped to 52o/o in Bellevue and 54% in
Ketchum.
We found 63% aware of the ldaho Power's proposal to build a redundant power
transmission line between the substation north of Hailey and the Ketchum substation.
18-34 year olds and 75+ respondents were marginally less aware of the proposal, and
men were marginally more aware of it then women. !t dropped to 50% in Ketchum and
43o/o in Bellevue.
We found 42o/o dwile of the fact that Blaine County, if ordered by the Public
Utility Commission, must allow Idaho Power to build the redundant transmission line.
This dropped to 30% in Bellevue and 32o/o in Ketchum. Men were more aware than
women by a 13% margin. Only 22o/o of respondents 75+ were aware of this information.
When we asked respondents if they would be willing to pav an addition fee or
lew for the line to be underqrounded south of Elkhorn Road, 51% said yes and 34o/o no
with 15% not sure. Support significantly increased among those very aware of the
scenery between Hailey and Ketchum, those who said it was very important that the
scenery remain unobstructed and among those aware that Blaine County must allow
ldaho Power to build the line. lf respondents supported Option 1 over Option 2 and
Option 3, then they strongly supported paying an additionalfee or levy. Those in the
unincorporated area of the county (NET +28o/o) were most willing to pay the additional
fee while those in the balance of the county were less willing (Bellevue NET +9% and
Ketchum NET +7%). ln Hailey it was a NET +10o/o.
2
We then read a number of options starting with Option 1, the most expensive.
We found 52% supportive and 34% opposed with 14o/o not sure. Among those very
aware of the scenery and respondents wanting it to remain unobstructed and are willing
to pay an additional fee, we see support well above the norm. The one demographic
group that opposes Option 1 are respondents 75+ (Net -8%) and those who strongly
support Option 3.
Ootion 2 found 57o/o in support and 31 % opposed or a net margin ol 260/o versus
the net of 18o/o for Option 1 . With Option 2, we found a shift from opposition to support
among respondents 75+ (Net +17o/o'). Among those very aware of the scenery and it
being very important to them, we have more than two-thirds supporting Option 2.
Among those who supported Option 1 , 80o/o support Option 2. By a 620/o to 50%
margin, women support Option 2 over men. This option also found almost two-thirds
support in Ketchum.
Ootion 3 which would require all aboveground lines but at no cost to taxpayer
found 36% in support and 54o/o oppose with 10% not sure. lf a respondent supported
either Option 1 or Option 2, they did not support Option 3. We found no support among
our age groups, geographically or by gender. We did, however, find much stronger
opposition among women than among men.
After we read each individual option, we then asked respondents to tell us which
of the three they would most support. Here we found Option 1 at34Yo, Option 2 at31o/o
and 27o/o supporting Option 3. Support for Option 1 was greatest among those who
drive between Hailey and Ketchum seven or more times a week (50%), would support
additionalfees (49%) and are 3549 year olds $1Yol. Support for Option 2 found its
strongest base among those who traveled between Hailey and Ketchum once a week
and were 18-34 years old. Option 3 found support among those who did not drive
between the two cities weekly and men more than women. The reason Option 3 was
supported was "because this option would not cost them any money."
3
When we look at the numbers, Option 2 would be the one most likely to succeed
if this needed voter approval. 80% or more of Option 1 supporters would also support
Option 2 bringing it within reach of a two-thirds majority if required. Clearly, people in
Blaine County care about the "scenery'and oppose Option 3 even at no cost. A strong
argument can be made that Blaine County residents want to preserve the view
associated with the drive between Hailey and Ketchum.
What reinforces this argument is:
/ A strong, positive right direction response
{ A high Ievel of awareness of scenery
/ A high levelof importance for unobstructed views
r' A high level of awareness of the PUC's decision regarding North Valley service
r' A high level of awareness of ldaho Power proposal
This represents a well "educated' population that understands that transmission
lines are likely to be built but to varying degrees want them underground and most
assuredly not aboveground.
4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-25
IDAHO POWER COMPANY
REQUEST NO. 14
ATTACHMENT 3
Ft& 2020
lEac u[Ed[llEarwEmrtumE arN.r-' re u E us Dfletc cN E@CEMrc
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