20150630IRP Appendix C Technical Report.pdf

June 2015
Technical ReportAPPENDIX C
2015
IntegratedResourcePlan
June 2015
IDAHO
Ss POWER.
An IDACORP Company
ntegrated
Resource
APPENDIX C
Technical Report
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SAFE HARBOR STATEMENT
This document may contain forward-looking statements, and it is important to note that the future
results could differ materially from those discussed. A full discussion of the factors that could cause
future results to differ materially can be found in Idaho Power’s filings with the Securities and
Exchange Commission.
ACKNOWLEDGMENT
Resource planning is an ongoing process at Idaho Power. Idaho Power
prepares, files, and publishes an Integrated Resource Plan every two years.
Idaho Power expects that the experience gained over the next few years will
likely modify the 20-year resource plan presented in this document.
Idaho Power invited outside participation to help develop the 2015
Integrated Resource Plan. Idaho Power values the knowledgeable
input, comments, and discussion provided by the Integrated Resource
Plan Advisory Council and other concerned citizens and customers.
It takes approximately one year for a dedicated team of individuals at Idaho
Power to prepare the Integrated Resource Plan. The Idaho Power team is
comprised o f individuals t hat represent m any different d epartments within
the company. The Integrated Resource Plan team members are responsible
for preparing forecasts, working with the advisory council and the public,
and performing all the analyses necessary to prepare the resource plan.
Idaho Power looks forward to continuing the resource planning process with
customers, public interest groups, regulatory agencies, and other interested
parties. You can learn more about the Idaho Power resource planning
process at www.idahopower.com.
June 2015
2015
IntegratedResourcePlan
Technical ReportAPPENDIX C
Printed on recycled paper
Idaho Power Company Table of Contents
2015 Integrated Resource Plan—Appendix C Page i
TABLE OF CONTENTS
Table of Contents ............................................................................................................................. i
Introduction ......................................................................................................................................1
IRP Advisory Council and Members ...............................................................................................2
IRP Advisory Council Meeting Schedule and Agenda ..............................................................3
Public Policy Issues .........................................................................................................................5
Clean Air Act Section 111(d) Sensitivities Assumptions ..........................................................5
Flow Modeling ...........................................................................................................................7
Sales and Load Forecast Data ........................................................................................................10
Average Annual Forecast Growth Rates..................................................................................10
Expected-Case Load Forecast ..................................................................................................11
70th Percentile Load Forecast ...................................................................................................20
Load and Resource Balance Data ..................................................................................................29
Monthly Average Energy Load and Resource Balance ...........................................................29
Monthly Average Energy Surplus/Deficit Charts ....................................................................49
Peak-Hour Load and Resource Balance ..................................................................................50
Peak-Hour Surplus/Deficit Charts ...........................................................................................70
Demand-Side Resource Data .........................................................................................................71
Cost Effectiveness ....................................................................................................................71
Resource Development and Evaluation ...................................................................................71
Planning Assumptions and Alternate Costs .............................................................................72
Forecast and Cost-Effectiveness Data .....................................................................................73
Supply-Side Resource Data ...........................................................................................................83
Key Financial and Forecast Assumptions ................................................................................83
Cost Inputs and Operating Assumptions..................................................................................85
Transmission Cost Assumptions ..............................................................................................86
Levelized Cost of Production...................................................................................................89
Peak-Hour Capacity Credit (Contribution to Peak)—Solar and Wind Resources ..................90
Energy Shape—Solar ...............................................................................................................91
Schedule 87—Integration Costs for Solar and Wind Resources .............................................92
PURPA Reference Data .........................................................................................................119
Table of Contents Idaho Power Company
Page ii 2015 Integrated Resource Plan—Appendix C
Renewable Energy Certificate Price Forecast ........................................................................120
Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis.............................................121
Background ............................................................................................................................121
SCR Construction Progress Update .......................................................................................121
2015 Jim Bridger Units 3 and 4 SCR Analysis......................................................................122
Overall Analysis Methodology ..............................................................................................123
Option 1 NPV Methodology ..................................................................................................123
Option 2 NPV Methodology ..................................................................................................124
Analysis Results .....................................................................................................................124
Conclusions and Recommendations ......................................................................................124
Revenue Requirement Comparison between Jim Bridger Units 3 and 4 SCR Completion and
CCCT Replacement ...............................................................................................................125
Fuel Price Forecast .......................................................................................................................129
Natural Gas and Coal Price Forecast (nominal $/MMBtu) ...................................................129
Existing Resource Data ................................................................................................................131
Hydroelectric and Thermal Plant Data ..................................................................................131
Qualifying Facility Data (PURPA) ........................................................................................132
Power Purchase Agreement Data...........................................................................................134
Hydro Modeling Results (PDR580).......................................................................................135
Portfolio Analysis, Results, and Supporting Documentation ......................................................165
Portfolio Emissions ................................................................................................................165
Loss of Load Expectation Analysis .......................................................................................167
State of Oregon IRP Guidelines ...................................................................................................173
Compliance with State of Oregon IRP Guidelines ................................................................181
State of Oregon IRP Electric Vehicles (EV) Guidelines .............................................................187
Compliance with EV Guidelines ...........................................................................................191
State of Oregon Action Items Regarding Idaho Power’s 2013 IRP ............................................192
Compliance with State of Oregon IRP Guidelines ................................................................211

Idaho Power Company Introduction
2015 Integrated Resource Plan—Appendix C Page 1
INTRODUCTION
Appendix C–Technical Appendix contains supporting data and explanatory materials used to develop
Idaho Power’s 2015 Integrated Resource Plan (IRP).
The main document, the IRP, contains a full narrative of Idaho Power’s resource planning process.
Additional information regarding the 2015 IRP sales and load forecast is contained in Appendix A–Sales and Load Forecast, and details on Idaho Power’s demand-side management efforts are explained in Appendix B–Demand-Side Management 2014 Annual Report. The IRP, including the three appendices,
was filed with the Idaho and Oregon public utility commissions in June 2015.
For information or questions concerning the resource plan or the resource planning process,
contact Idaho Power:
Idaho Power—Resource Planning
1221 West Idaho Street
Boise, Idaho 83702
208-388-2623
[e-mail]

IRP Advisory Council Idaho Power Company
Page 2 2015 Integrated Resource Plan—Appendix C
IRP ADVISORY COUNCIL AND MEMBERS
Idaho Power has involved representatives of the public in the IRP planning process since the early
1990s. This public forum has come to be known as the IRP Advisory Council (IRPAC). The IRPAC generally meets monthly during the development of the IRP and the meetings are open to the public. Members of the council include political, environmental, and customer representatives, as well as
representatives of other public-interest groups.
As part of preparing the 2015 IRP, Idaho Power hosted a field trip to the Swan Falls hydroelectric
project and museum.. Idaho Power also hosted 12 IRPAC meetings, including a resource portfolio design workshop. Idaho Power and members from the IRPAC also met in several small break-out sessions to discuss certain topics in greater detail. Idaho Power values these opportunities to convene,
and the IRPAC members and the public have made significant contributions to this plan.
Idaho Power believes working with members of the IRPAC and the public is very rewarding, and the
IRP is better because of the public involvement. Idaho Power and the members of the IRPAC recognize that outside perspective is valuable, but also recognize that final decisions on the IRP are made by Idaho Power.
Customer Representatives
Public Interest Representatives
Boise Metro Chamber of Commerce ................................... Ray Stark
Idaho Conservation League ................................................. Ben Otto
Idaho Department of Commerce ......................................... Chrissy Bowers
Idaho Legislature ................................................................. Representative Robert Anderst
Idaho Office of Energy Resources....................................... John Chatburn
Idaho Technology Council .................................................. Jay Larsen
Northwest Power and Conservation Council....................... Shirley Lindstrom/Jim Yost
Oil and Gas Industry Advisor .............................................. David Hawk
Oregon State University – Malheur Experiment Station ..... Clint Shock
Snake River Alliance ........................................................... Ken Miller
University of Idaho Center for Ecohydraulics Research ..... Daniele Tonina
University of Idaho Integrated Design Lab ......................... Kevin Van Den Wymelenberg
Water Issues Advisor ........................................................... Vince Alberdi
Regulatory Commission Representatives
Idaho Public Utilities Commission ...................................... Stacey Donohue
Public Utility Commission of Oregon ................................. Michael Breish
Idaho Power Company IRP Advisory Council
2015 Integrated Resource Plan—Appendix C Page 3
IRP Advisory Council Meeting Schedule and Agenda
Meeting Dates Agenda Items
2014 Thursday, August 7 Introductions/meeting overview
Welcome and opening remarks
IRP process explanation
System load and operation
Demand response update
Natural gas forecast
Solar workgroup recap
2014 Thursday, September 4 Review of August IRPAC meeting
Solar workgroup recap
Coal study workgroup recap
Natural gas forecast
Overview of Idaho Power generation and transmission
Resource stack introduction
2014 Wednesday, October 1 Field trip to Swan Falls hydroelectric project and museum
2014 Thursday, October 2 Review of September IRPAC meeting
2015 IRP load forecast
Resource stack capital costs
IRP risk factors
2014 Thursday, November 6 Review of October IRPAC meeting
Coal study
Demand-side management
Water supply forecast
Cloud seeding
Hydro generation forecast
2014 Thursday, December 4 Review of November IRPAC meeting
Recap of DSM working group meeting
Clean Air Act Section 111(d)
500-kV transmission projects
Power markets
2015 Thursday, January 8 Review of December IRPAC meeting
Recap of DSM working group meetings
Energy efficiency potential study final results
PURPA/PPA forecast
Resource stack
2015 Wednesday, January 28 Portfolio design workshop
2015 Thursday, February 5 Review of January IRPAC meeting
AURORA overview
Load and resource balance
Portfolio design
2015 Thursday, March 12 Review of February IRPAC meeting
Conservation voltage reduction update
2015 IRP resource portfolios
Portfolio analysis overview
IRP Advisory Council Idaho Power Company
Page 4 2015 Integrated Resource Plan—Appendix C
Meeting Dates Agenda Items
2015 Thursday, April 2 Review of March IRPAC meeting
Portfolio analysis results
Sustainability at Idaho Power
Hells Canyon Complex relicensing
2015 Thursday, May 7 Review of April IRPAC meeting
Clean Air Act Section 111(d) sensitivity analysis
Stochastic risk analysis
Asset replacement deferment
End of feeder solar project
Flexibility analysis
Operational impacts of oversupply
2015 Thursday, June 4 Review of May IRPAC meeting
Preferred portfolio discussion
Tipping point analysis
Natural gas outlook from Potential Gas Committee
Shoshone Falls expansion
Loss of load expectation analysis
2015 IRP action plan
Input for the 2017 IRP and public process

Idaho Power Company Public Policy Issues
2015 Integrated Resource Plan—Appendix C Page 5
PUBLIC POLICY ISSUES
Clean Air Act Section 111(d) Sensitivities Assumptions
Section 111(d) Sensitivities
Because of the uncertainty associated with the EPA’s proposed regulation of CO2 under the Clean Air
Act of 1970 (CAA) Section 111(d), a range of sensitivities was modeled. Each sensitivity is based on
multiple assumptions as provided in this section. It is noted that portfolio cost results associated with
each sensitivity are contingent upon underlying assumptions of the sensitivity; stipulations for the final
CAA Section 111(d) regulation may differ greatly from those assumed for these sensitivities, leading possibly to markedly different costs in practice.
Null Sensitivity (No CAA Section 111(d))
• No existing regulations require any modifications to operations or equipment
• No pending or future regulations (i.e., CAA Section 111(d)) will require any modifications to
operations or equipment
• Analyzed to provide a comparison with portfolios complying with CAA Section 111(d)-based
regulations on CO2 emissions
State-by-State Mass-Based Compliance
• Compliance determined within state boundaries
• Compliance cannot cross state lines and plant reductions cannot be shifted across state lines
• Converting from rate base to mass base using percent reduction from rate goals established by proposed regulation
• No requirements for renewable energy or energy efficiency
• Generation is capped at the target levels
o North Valmy targets—574,382 MWh/year for 2020-2029 and 533,343 MWh/year for 2030 through IRP planning period end
o Jim Bridger targets—3,914,502 MWh/year for 2020-2029 and 3,675,608 MWh/year for
2030 through IRP planning period end
o Langley Gulch target alternatives
 30 percent annual capacity factor for 2020 through IRP planning period end (837,018 MWh/year)
 55 percent annual capacity factor for 2020 through IRP planning period end
(1,534,533 MWh/year)
 70 percent annual capacity factor for 2020 through IRP planning period end
(1,953,042 MWh/year)
Public Policy Issues Idaho Power Company
Page 6 2015 Integrated Resource Plan—Appendix C
System-Wide Mass-Based Compliance
• Determine total CO2 reduction for Idaho Power system
• Compliance is determined by meeting Idaho Power system CO2 emission target
• Compliance can cross state lines and plant CO2 reductions can be shifted across state lines
• Converting from rate base to mass base using percent reduction from rate goals established by
proposed regulation
• No requirements for renewable energy or energy efficiency
• Idaho Power system emissions are capped at the target levels
o 6,332,020 tons CO2 for 2020–2029
o 5,925,874 tons CO2 for 2030 through IRP planning period end
• Early shutdown of units enables other units to increase generation
Emissions Intensity Compliance Utilizing the EPA’s Compliance Building Blocks
• All building blocks required to meet compliance
• Rate reductions established based on the goal calculations by the EPA
• The state of Idaho is able to count previously constructed PURPA projects as part of building
block 3
• Renewable energy (building block 3) and energy efficiency (building block 4) in Idaho grow to
EPA projected levels
• No renewable energy or energy efficiency requirements for states where Idaho Power has no customers (Wyoming, Nevada)
• CAA Section 111(d) CO2 attributes can cross state lines
• Affected unit generation and renewable energy/energy efficiency are variable as long as interim
and final rates are met
• Idaho Power is not responsible for meeting interim or final goals for Wyoming, Nevada, or Oregon
• Since Boardman has an agreed upon closure date, Idaho Power has no rate requirements to meet
in Oregon
• Interim goals are relaxed with agreed upon retirement dates for Boardman and North Valmy set
at 2020 and 2025 respectively (note that pre-2025 North Valmy retirement also allows a relaxing of interim goals)
• Building block 1 (6 percent efficiency improvement) cannot be met or sustained and is reset to
0 percent
• Jim Bridger generation reduced from 2012 levels for pro-rata share of 95 MW natural gas plant
under construction in Wyoming (building block 2)
• Generation capped at the target levels
o North Valmy target—814,264 MWh/year until retirement (retirement no later than 2025)
Idaho Power Company Public Policy Issues
2015 Integrated Resource Plan—Appendix C Page 7
o Jim Bridger target—4,488,392 MW/year for 2020 through IRP planning period end
o Langley Gulch target alternatives
 30 percent annual capacity factor for 2020 through IRP planning period end
(837,018 MWh/year)
 55 percent annual capacity factor for 2020 through IRP planning period end
(1,534,533 MWh/year)
 70 percent annual capacity factor for 2020 through IRP planning period end
(1,953,042 MWh/year)
Flow Modeling
Models
Idaho Power uses two primary models for forecasting future flows for the IRP. The Snake River
Planning Model (SRPM) is used to forecast surface water flows and the Enhanced Snake Plain Aquifer
Model (ESPAM) is used to forecast the impact of various aquifer management practices implemented on the Eastern Snake Plain Aquifer (ESPA). The SRPM was updated in late 2012 to include hydrologic conditions for years 1928 through 2009. ESPAM was also updated with the release of ESPAM 2.1 in
late 2012. Beginning with the 2009 IRP, Idaho Power began running the SRPM and ESPAM as a
combined modeling system. The combined model seeks to maximize diversions for aquifer recharge and
system conversions without creating additional model irrigation shortages over a modeled reference condition.
Model Inputs
The model inputs used in this effort are similar to the inputs used in the 2011 and 2013 IRP but those
inputs continued to be refined to reflect future system conditions and management policies. The general
inputs to the model are reach declines, weather modification, aquifer recharge, system conversions,
and retirement of land from irrigation.
Future reach declines were determined using a variety of statistical analysis. Trend data indicate reach gains into American Falls Reservoir and from Milner Dam to Lower Salmon Falls Dam demonstrated a
statistically significant decline for the period of 1980 to 2013. Reach gains into American Falls
Reservoir declined on average 23 cubic feet per second per month (cfs/month) with declines ranging
from 12 to 34 cfs/month. Reach gains from Milner Dam to Lower Salmon Falls Dam for American
declined on average 34 cubic feet per second per month (cfs/month) with declines ranging from 22 to 53 cfs/month. Declines in these two reaches met strict, predefined criteria and were therefore included as
inputs into the model.
Weather modification was added to the model at different levels of development. For IRP years
2015 through 2019, weather modification was increased to reflect projected levels of fully built-out
programs in Eastern Idaho, the Wood River Valley, and the Boise Basin. Beyond IRP year 2019, weather modification levels in these three basins were held constant through the rest of the IRP forecast
period. The level of weather modification was held constant at the current level in the Payette River
Basin throughout the IRP forecast period. The amount of weather modification added to each year is
Public Policy Issues Idaho Power Company
Page 8 2015 Integrated Resource Plan—Appendix C
based on the total runoff for each year from 1928 through 2009. At full build out the Payette basin
increase total discharge by an average of 271,567 acre-ft/year. The Upper Snake, Wood River,
and Boise Basins, respectively, add an average of 453,130 acre-ft/year; 108,900 acre-ft/year;
and 218,249 acre-ft/year by IRP year 2019.
Aquifer recharge was added to the model at levels reflected in the 2014 Idaho Water Resource Board
Preliminary Draft—Managed Recharge Plan. In the 2015 IRP, recharge expanded to include wintertime
recharge from winter time diversions at Milner Dam. Recharge peaks in IRP year 2021 at approximately
209,839 acre-ft and then slowly declines as diminishing reach gains limit the amount of water available
for aquifer recharge.
System conversion projects involve the conversion of ground water supplied irrigated land to surface
supplied irrigated land. The number of acres modeled and potential water savings was based on data
provided by the Idaho Department of Water Resources (IDWR). The current model assumes a total of
14,767 acres of converted land on the ESPA with a total water savings of 2.0 acre-ft or water per acre of
irrigated land (acre-ft/ac). Additional conversion projects are added to the model and from 2020 to 2034 they are held constant at 16,687 acres. Diversions for conversion projects are limited by water
availability to meet the demand. Diversions for conversion projects peak in 2020 at 32,440 acre-ft.
Diversions for conversion project generally declines after 2020 at declines in reach gains reduces water
availability for diversion.
The model accounts for approximately 15,140 acres that are currently in the Conservation Reserve Enhancement Program (CREP). These acres are idled under a 15-year contract with the
U.S. Department of Agriculture. Each idled acre is credited in the ESPAM model for reducing irrigation
withdrawal from the ESPA by 2.0 acre-ft/year. Many of the CREP contracts were initiated in 2006 and
are set to retire beginning in 2020. The current model phases out CREP acres over a four-year period
and includes no idled acres by IRP year 2024. The reduction in CREP acres further results in reducing the amount of water available for other management activities such as aquifer recharge and
system conversions. Also included in this model run are 750 acres of short-term projects to reduce water
use by ground water appropriators. The projects may include the elimination of end gun on center pivots
or drying pivot corners. These short-term projects run from 2015 to 2023.
Model Results
The combined model allows for the ability to include future management activities, and the resulting reach gains from those management activities into Idaho Power’s 2015 IRP. Management activities, such as recharge and system conversions, do not significantly change the total annual volume of water
expected to flow through the Hells Canyon Complex, but instead change the timing and location of
reach gains within the system. Other future management activities, such as weather modification and
CREP do directly impact the annual volume of water expected through the Hells Canyon Complex as well as the timing and location of gains within the system.
Overall flow through the Hells Canyon Complex increases from IRP year 2015 through 2019 in
response to increased weather modification in the Upper Snake, Wood and Boise River Basins.
Flows peak in 2019 with the 50 percent exceedance flows into Brownlee Reservoir as just over
11.9 million acre-ft/year. In 2034, those flows have declined to approximately 11.3 million acre-ft/year,
Idaho Power Company Public Policy Issues
2015 Integrated Resource Plan—Appendix C Page 9
with most of the declines attributable to declining flows into American Falls and the Milner to Lower
Salmon Falls reach.
2015 Model Parameters
Managed Recharge (acft/yr) Weather Modification (acft/yr)
System Conversions (Ac) CREP (Ac)
Reach Declines (acft/yr)
IRP Year Above American Falls Below American Falls Total American Falls Inflows Below Milner Inflows
2015 34,060 29,793 63,852 715,209 14,767 15,890 102,644 152,147
2016 33,896 29,772 63,668 840,784 14,767 15,890 119,751 177,504
2017 34,339 69,965 104,304 960,948 14,767 15,890 136,858 202,862
2018 35,417 94,061 129,478 1,017,289 15,407 15,890 153,966 228,220
2019 43,433 168,533 211,966 1,051,936 16,047 15,890 171,073 253,578
2020 42,926 167,127 210,052 1,051,936 16,687 12,033 188,180 278,936
2021 42,989 166,850 209,839 1,051,936 16,687 8,312 205,287 304,293
2022 42,795 166,640 209,435 1,051,936 16,687 4,531 222,395 329,651
2023 42,599 166,983 209,582 1,051,936 16,687 2,056 239,502 355,009
2024 42,265 164,705 206,970 1,051,936 16,687 0 256,609 380,367
2025 42,272 164,293 206,565 1,051,936 16,687 0 273,717 405,724
2026 42,271 163,541 205,812 1,051,936 16,687 0 290,824 431,082
2027 42,021 162,395 204,416 1,051,936 16,687 0 307,931 456,440
2028 42,240 162,839 205,079 1,051,936 16,687 0 325,039 481,798
2029 42,389 163,178 205,567 1,051,936 16,687 0 342,146 507,156
2030 42,129 162,217 204,346 1,051,936 16,687 0 359,253 532,513
2031 41,716 161,734 203,450 1,051,936 16,687 0 376,360 557,871
2032 41,715 161,600 203,315 1,051,936 16,687 0 393,468 583,229
2033 41,887 161,659 203,545 1,051,936 16,687 0 410,575 608,587
2034 42,189 163,380 205,570 1,051,936 16,687 0 427,682 633,944

Sales and Load Forecast Data Idaho Power Company
Page 10 2015 Integrated Resource Plan—Appendix C
SALES AND LOAD FORECAST DATA
Average Annual Forecast Growth Rates
2015–2020 2015–2025 2015–2034

Residential Sales ................................................................1.57% 1.40% 1.33%
Commercial Sales................................................................1.02% 1.00% 0.98%
Irrigation Sales ................................................................................................0.62% 0.51% 0.49%
Industrial Sales ................................................................................................2.91% 2.36% 1.99%
Additional Firm Sales ................................................................0.89% 1.35% 0.64%
System Sales ................................................................................................1.48% 1.34% 1.20%
Total Sales ................................................................................................1.48% 1.34% 1.20%
Loads
Residential Load ................................................................1.56% 1.40% 1.32%
Commercial Load................................................................1.02% 0.99% 0.98%
Irrigation Load ................................................................................................0.56% 0.51% 0.49%
Industrial Load ................................................................................................2.78% 2.32% 1.97%
Additional Firm Sales ................................................................0.89% 1.35% 0.64%
System Load Losses ................................................................1.37% 1.25% 1.16%
System Load ................................................................................................1.43% 1.32% 1.19%
Total Load ................................................................................................1.43% 1.32% 1.19%
Peaks
System Peak ................................................................................................1.78% 1.66% 1.53%
Total Peak ................................................................................................1.78% 1.66% 1.53%
Winter Peak ................................................................................................0.91% 0.93% 0.88%
Summer Peak ................................................................................................1.78% 1.66% 1.53%
Customers
Residential Customers ................................................................2.13% 1.88% 1.62%
Commercial Customers ................................................................2.03% 1.91% 1.72%
Irrigation Customers ................................................................1.40% 1.35% 1.28%
Industrial Customers ................................................................0.53% 0.69% 0.66%

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 11
Expected-Case Load Forecast
Monthly Summary 1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015
Average Load (aMW)–50 Percentile
Residential 753 705 609 510 440 462 669 543 457 481 590 843
Commercial 482 470 446 433 428 454 534 475 461 453 448 503
Irrigation 2 2 5 89 302 536 659 544 311 77 5 3
Industrial 277 274 276 262 256 281 279 282 279 288 283 285
Additional Firm 105 103 99 101 95 100 98 98 101 100 104 103
Loss ................................139 133 122 119 131 160 199 171 138 118 121 150
System Load 1,759 1,688 1,556 1,513 1,652 1,994 2,438 2,113 1,747 1,517 1,551 1,887
Light Load 1,634 1,551 1,421 1,369 1,493 1,801 2,206 1,870 1,557 1,365 1,429 1,741
Heavy Load 1,858 1,791 1,663 1,618 1,790 2,135 2,621 2,304 1,898 1,627 1,658 2,002
Total Load 1,759 1,688 1,556 1,513 1,652 1,994 2,438 2,113 1,747 1,517 1,551 1,887
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,264 2,342 2,072 2,017 2,649 3,109 3,537 2,995 2,887 2,117 2,170 2,603
Total Peak Load 2,264 2,342 2,072 2,017 2,649 3,109 3,537 2,995 2,887 2,117 2,170 2,603

Monthly Summary 1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016
Average Load (aMW)–50 Percentile
Residential 771 721 623 521 451 475 688 558 468 492 603 860
Commercial 490 477 453 440 435 462 543 483 469 461 456 509
Irrigation 2 2 5 90 308 547 673 556 317 79 5 3
Industrial 296 283 294 279 273 300 297 301 298 307 302 293
Additional Firm 110 105 105 104 97 94 101 101 99 101 105 109
Loss ................................143 136 125 122 135 164 204 175 142 121 124 153
System Load 1,813 1,724 1,605 1,557 1,700 2,042 2,507 2,175 1,794 1,561 1,594 1,927
Light Load 1,683 1,584 1,466 1,409 1,536 1,844 2,268 1,924 1,600 1,404 1,469 1,778
Heavy Load 1,924 1,828 1,706 1,666 1,841 2,186 2,712 2,355 1,950 1,684 1,695 2,044
Total Load 1,813 1,724 1,605 1,557 1,700 2,042 2,507 2,175 1,794 1,561 1,594 1,927
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,334 2,378 2,125 2,072 2,714 3,211 3,630 3,087 2,978 2,167 2,218 2,640
Total Peak Load 2,334 2,378 2,125 2,072 2,714 3,211 3,630 3,087 2,978 2,167 2,218 2,640

Monthly Summary 1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017
Average Load (aMW)–50 Percentile
Residential 785 733 634 531 460 485 704 571 478 500 613 873
Commercial 495 481 457 444 439 466 547 488 474 466 460 514
Irrigation 2 2 5 91 311 551 678 560 320 79 5 3
Industrial 304 300 302 287 280 308 305 309 306 315 310 299
Additional Firm 111 110 106 105 97 94 102 102 100 101 105 109
Loss ................................145 139 127 123 137 166 207 178 144 123 126 155
System Load 1,842 1,765 1,630 1,581 1,725 2,071 2,543 2,207 1,822 1,585 1,619 1,953
Light Load 1,710 1,621 1,489 1,431 1,558 1,871 2,301 1,953 1,624 1,426 1,492 1,802
Heavy Load 1,955 1,872 1,732 1,701 1,856 2,217 2,752 2,390 1,980 1,710 1,722 2,082
Total Load 1,842 1,765 1,630 1,581 1,725 2,071 2,543 2,207 1,822 1,585 1,619 1,953
Peak Load (MW)–90th Percentile
System Peak (1 hour) 2,360 2,414 2,148 2,093 2,755 3,266 3,696 3,137 3,027 2,193 2,242 2,664
Total Peak Load 2,360 2,414 2,148 2,093 2,755 3,266 3,696 3,137 3,027 2,193 2,242 2,664
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 12 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018
Average Load (aMW)–50 Percentile
Residential 794 741 641 537 467 493 715 580 485 506 620 884
Commercial 498 483 459 447 442 470 551 492 478 469 463 518
Irrigation 2 2 5 91 311 552 679 560 320 79 5 3
Industrial 309 306 308 292 286 314 311 315 312 321 316 304
Additional Firm 112 110 106 105 98 94 102 102 100 102 106 110
Loss ................................147 140 129 125 138 168 209 179 146 124 127 157
System Load 1,863 1,783 1,647 1,597 1,741 2,090 2,568 2,228 1,841 1,602 1,637 1,975
Light Load 1,730 1,638 1,504 1,445 1,573 1,888 2,323 1,972 1,641 1,441 1,508 1,823
Heavy Load 1,968 1,892 1,750 1,719 1,874 2,238 2,778 2,413 2,015 1,718 1,740 2,106
Total Load 1,863 1,783 1,647 1,597 1,741 2,090 2,568 2,228 1,841 1,602 1,637 1,975
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,367 2,425 2,157 2,099 2,786 3,302 3,752 3,170 3,062 2,212 2,250 2,681
Total Peak Load 2,367 2,425 2,157 2,099 2,786 3,302 3,752 3,170 3,062 2,212 2,250 2,681

Monthly Summary 1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019
Average Load (aMW)–50 Percentile
Residential 803 748 647 543 473 500 727 589 492 511 626 893
Commercial 502 487 462 450 446 474 556 496 483 473 467 523
Irrigation 2 2 5 91 310 551 677 559 319 79 5 3
Industrial 315 311 313 297 291 319 316 320 317 327 321 309
Additional Firm 112 110 106 105 98 94 102 102 100 102 106 110
Loss ................................149 142 130 126 139 169 211 181 147 126 129 159
System Load 1,883 1,800 1,664 1,612 1,756 2,107 2,589 2,247 1,858 1,618 1,654 1,996
Light Load 1,748 1,654 1,519 1,459 1,587 1,903 2,342 1,989 1,656 1,455 1,523 1,842
Heavy Load 1,989 1,910 1,777 1,725 1,890 2,270 2,783 2,434 2,034 1,735 1,758 2,128
Total Load 1,883 1,800 1,664 1,612 1,756 2,107 2,589 2,247 1,858 1,618 1,654 1,996
Peak Load (MW)–90th Percentile
System Peak (1 hour) 2,514 2,388 2,072 1,992 2,950 3,362 3,555 3,161 2,907 2,090 2,260 2,668
Total Peak Load 2,514 2,388 2,072 1,992 2,950 3,362 3,555 3,161 2,907 2,090 2,260 2,668

Monthly Summary 1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020
Average Load (aMW)–50 Percentile
Residential 810 753 652 547 477 505 735 596 497 515 630 901
Commercial 507 490 466 454 450 479 561 501 488 478 471 528
Irrigation 2 2 5 92 312 554 681 562 321 80 5 3
Industrial 320 306 318 302 296 325 322 326 322 332 327 315
Additional Firm 113 108 107 107 99 96 103 103 101 103 107 111
Loss ................................150 142 131 127 140 171 213 183 149 127 130 161
System Load 1,902 1,801 1,680 1,628 1,774 2,129 2,615 2,271 1,878 1,634 1,670 2,019
Light Load 1,766 1,655 1,534 1,473 1,603 1,923 2,366 2,009 1,674 1,470 1,539 1,863
Heavy Load 2,009 1,909 1,794 1,742 1,921 2,279 2,811 2,477 2,041 1,753 1,786 2,142
Total Load 1,902 1,801 1,680 1,628 1,774 2,129 2,615 2,271 1,878 1,634 1,670 2,019
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,414 2,457 2,193 2,135 2,848 3,372 3,862 3,236 3,129 2,248 2,288 2,725
Total Peak Load 2,414 2,457 2,193 2,135 2,848 3,372 3,862 3,236 3,129 2,248 2,288 2,725
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 13
Monthly Summary 1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021
Average Load (aMW)–50 Percentile
Residential 818 759 658 552 483 512 746 604 503 520 636 911
Commercial 512 494 470 458 455 483 566 506 494 482 476 534
Irrigation 2 2 5 92 314 557 685 566 323 80 5 3
Industrial 326 323 324 308 301 331 328 332 328 338 333 320
Additional Firm 113 112 108 107 99 96 103 103 101 103 107 112
Loss ................................152 144 132 128 142 173 215 185 150 128 131 162
System Load 1,923 1,834 1,697 1,645 1,793 2,152 2,643 2,296 1,899 1,652 1,688 2,041
Light Load 1,785 1,685 1,550 1,489 1,620 1,944 2,391 2,032 1,693 1,486 1,555 1,884
Heavy Load 2,041 1,946 1,803 1,760 1,942 2,304 2,842 2,504 2,064 1,782 1,795 2,166
Total Load 1,923 1,834 1,697 1,645 1,793 2,152 2,643 2,296 1,899 1,652 1,688 2,041
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,429 2,473 2,207 2,148 2,882 3,415 3,922 3,275 3,168 2,268 2,302 2,744
Total Peak Load 2,429 2,473 2,207 2,148 2,882 3,415 3,922 3,275 3,168 2,268 2,302 2,744

Monthly Summary 1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022
Average Load (aMW)–50 Percentile
Residential 825 765 663 557 488 518 756 612 508 524 641 920
Commercial 516 498 474 462 459 488 571 511 499 487 480 539
Irrigation 2 2 5 92 315 559 687 567 324 80 5 3
Industrial 332 329 330 314 307 337 334 338 334 345 339 326
Additional Firm 119 117 112 111 102 99 106 106 104 107 112 117
Loss ................................153 146 134 130 143 174 217 187 152 129 133 164
System Load 1,948 1,856 1,718 1,666 1,814 2,176 2,672 2,322 1,922 1,672 1,710 2,070
Light Load 1,809 1,705 1,569 1,507 1,639 1,965 2,417 2,055 1,714 1,505 1,575 1,910
Heavy Load 2,067 1,969 1,825 1,781 1,964 2,330 2,890 2,515 2,089 1,805 1,818 2,196
Total Load 1,948 1,856 1,718 1,666 1,814 2,176 2,672 2,322 1,922 1,672 1,710 2,070
Peak Load (MW)–90th Percentile
System Peak (1 hour) 2,448 2,491 2,225 2,162 2,917 3,456 3,981 3,313 3,207 2,291 2,320 2,770
Total Peak Load 2,448 2,491 2,225 2,162 2,917 3,456 3,981 3,313 3,207 2,291 2,320 2,770

Monthly Summary 1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023
Average Load (aMW)–50 Percentile
Residential 834 772 670 563 494 526 767 622 515 529 647 933
Commercial 521 502 478 466 463 493 576 516 505 492 485 545
Irrigation 2 2 5 92 315 559 688 568 324 81 5 3
Industrial 338 335 336 319 312 343 340 344 340 351 345 332
Additional Firm 123 121 116 114 105 102 109 109 107 110 115 121
Loss ................................155 147 135 131 145 176 220 188 154 131 134 166
System Load 1,974 1,879 1,740 1,686 1,835 2,199 2,700 2,347 1,945 1,693 1,732 2,100
Light Load 1,833 1,726 1,589 1,526 1,658 1,987 2,443 2,077 1,734 1,524 1,595 1,938
Heavy Load 2,095 1,994 1,848 1,814 1,974 2,355 2,921 2,542 2,114 1,827 1,841 2,239
Total Load 1,974 1,879 1,740 1,686 1,835 2,199 2,700 2,347 1,945 1,693 1,732 2,100
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,475 2,514 2,247 2,183 2,953 3,498 4,041 3,352 3,246 2,314 2,343 2,799
Total Peak Load 2,475 2,514 2,247 2,183 2,953 3,498 4,041 3,352 3,246 2,314 2,343 2,799
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 14 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024
Average Load (aMW)–50 Percentile
Residential 845 782 678 571 501 535 781 633 523 536 655 946
Commercial 526 506 482 470 468 498 582 521 511 497 490 550
Irrigation 2 2 5 93 317 562 691 571 326 81 5 3
Industrial 344 329 342 325 318 349 346 350 346 357 351 338
Additional Firm 126 119 118 117 107 104 111 111 109 112 118 124
Loss ................................157 148 137 133 147 178 222 191 155 133 136 169
System Load 2,001 1,886 1,762 1,708 1,857 2,226 2,733 2,376 1,970 1,715 1,755 2,130
Light Load 1,858 1,733 1,609 1,545 1,678 2,011 2,472 2,103 1,757 1,543 1,617 1,966
Heavy Load 2,114 1,999 1,882 1,826 1,999 2,398 2,938 2,574 2,157 1,840 1,866 2,271
Total Load 2,001 1,886 1,762 1,708 1,857 2,226 2,733 2,376 1,970 1,715 1,755 2,130
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,507 2,537 2,272 2,208 2,991 3,546 4,105 3,397 3,291 2,338 2,370 2,830
Total Peak Load 2,507 2,537 2,272 2,208 2,991 3,546 4,105 3,397 3,291 2,338 2,370 2,830

Monthly Summary 1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025
Average Load (aMW)–50 Percentile
Residential 857 791 687 578 509 544 795 644 532 543 663 959
Commercial 531 510 486 474 472 504 587 527 516 502 494 556
Irrigation 2 2 5 94 319 566 696 574 328 81 5 3
Industrial 350 347 348 331 323 355 352 357 353 364 358 344
Additional Firm 126 124 118 117 107 104 111 111 109 112 118 124
Loss ................................159 150 138 134 148 180 225 193 157 134 137 171
System Load 2,025 1,924 1,783 1,727 1,879 2,252 2,766 2,405 1,995 1,736 1,776 2,157
Light Load 1,881 1,768 1,628 1,563 1,698 2,034 2,502 2,129 1,779 1,562 1,636 1,991
Heavy Load 2,140 2,041 1,904 1,847 2,022 2,427 2,973 2,624 2,168 1,861 1,898 2,288
Total Load 2,025 1,924 1,783 1,727 1,879 2,252 2,766 2,405 1,995 1,736 1,776 2,157
Peak Load (MW)–90th Percentile
System Peak (1 hour) 2,535 2,559 2,294 2,230 3,027 3,594 4,168 3,442 3,335 2,361 2,394 2,857
Total Peak Load 2,535 2,559 2,294 2,230 3,027 3,594 4,168 3,442 3,335 2,361 2,394 2,857

Monthly Summary 1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026
Average Load (aMW)–50 Percentile
Residential 868 801 696 586 517 553 809 655 540 550 671 973
Commercial 536 514 490 478 477 509 593 532 522 507 499 562
Irrigation 2 2 5 94 321 569 700 578 330 82 5 3
Industrial 356 353 354 337 329 362 358 363 359 370 364 350
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................161 152 140 136 150 182 227 195 159 136 139 173
System Load 2,050 1,945 1,803 1,747 1,900 2,278 2,798 2,434 2,019 1,756 1,796 2,184
Light Load 1,903 1,787 1,646 1,581 1,717 2,058 2,532 2,154 1,800 1,580 1,654 2,015
Heavy Load 2,165 2,064 1,926 1,868 2,058 2,439 3,008 2,655 2,194 1,883 1,920 2,317
Total Load 2,050 1,945 1,803 1,747 1,900 2,278 2,798 2,434 2,019 1,756 1,796 2,184
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,561 2,578 2,315 2,251 3,064 3,643 4,231 3,486 3,379 2,384 2,416 2,883
Total Peak Load 2,561 2,578 2,315 2,251 3,064 3,643 4,231 3,486 3,379 2,384 2,416 2,883
The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 15
Monthly Summary 1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027
Average Load (aMW)–50 Percentile
Residential 880 810 704 593 524 562 823 667 548 557 679 987
Commercial 541 518 493 482 481 514 598 537 528 511 504 567
Irrigation 2 2 5 95 323 573 704 581 332 82 5 3
Industrial 363 359 360 342 335 368 364 369 365 376 370 356
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................163 154 141 137 152 184 230 198 161 137 141 175
System Load 2,074 1,966 1,823 1,766 1,922 2,304 2,830 2,462 2,043 1,776 1,816 2,211
Light Load 1,926 1,806 1,664 1,598 1,736 2,081 2,560 2,179 1,821 1,598 1,673 2,041
Heavy Load 2,202 2,086 1,937 1,889 2,081 2,467 3,043 2,686 2,220 1,916 1,931 2,346
Total Load 2,074 1,966 1,823 1,766 1,922 2,304 2,830 2,462 2,043 1,776 1,816 2,211
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,587 2,598 2,335 2,271 3,100 3,690 4,293 3,530 3,423 2,406 2,437 2,910
Total Peak Load 2,587 2,598 2,335 2,271 3,100 3,690 4,293 3,530 3,423 2,406 2,437 2,910

Monthly Summary1 1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028
Average Load (aMW)–50 Percentile
Residential 892 820 713 601 532 572 838 678 557 564 687 1,000
Commercial 546 522 498 486 486 519 603 542 534 517 508 573
Irrigation 2 2 5 95 324 575 708 584 334 83 5 3
Industrial 369 352 367 348 340 374 371 375 371 383 376 362
Additional Firm 125 118 117 116 106 103 110 110 108 111 117 123
Loss ................................165 155 143 139 153 186 233 200 163 139 142 178
System Load 2,098 1,969 1,843 1,785 1,943 2,329 2,862 2,490 2,067 1,796 1,837 2,239
Light Load 1,948 1,809 1,683 1,616 1,755 2,104 2,590 2,204 1,843 1,615 1,692 2,066
Heavy Load 2,227 2,088 1,958 1,921 2,090 2,494 3,097 2,697 2,246 1,938 1,953 2,387
Total Load 2,098 1,969 1,843 1,785 1,943 2,329 2,862 2,490 2,067 1,796 1,837 2,239
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,615 2,617 2,357 2,293 3,137 3,738 4,355 3,574 3,466 2,428 2,460 2,937
Total Peak Load 2,615 2,617 2,357 2,293 3,137 3,738 4,355 3,574 3,466 2,428 2,460 2,937

Monthly Summary 1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029
Average Load (aMW)–50th Percentile
Residential 904 830 722 609 540 581 852 690 566 571 696 1,013
Commercial 551 526 502 491 491 524 609 548 540 522 513 579
Irrigation 2 2 5 96 326 579 712 588 336 83 5 3
Industrial 375 371 373 354 346 381 377 382 378 389 383 367
Additional Firm 125 123 117 116 106 103 110 110 108 111 117 123
Loss ................................167 157 145 140 155 188 235 202 165 140 144 180
System Load 2,124 2,009 1,864 1,806 1,965 2,356 2,896 2,520 2,092 1,817 1,858 2,265
Light Load 1,972 1,846 1,702 1,634 1,775 2,128 2,620 2,230 1,865 1,634 1,712 2,090
Heavy Load 2,244 2,131 1,980 1,943 2,114 2,523 3,133 2,730 2,291 1,948 1,976 2,415
Total Load 2,124 2,009 1,864 1,806 1,965 2,356 2,896 2,520 2,092 1,817 1,858 2,265
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,642 2,638 2,378 2,314 3,174 3,788 4,419 3,621 3,512 2,452 2,483 2,963
Total Peak Load 2,642 2,638 2,378 2,314 3,174 3,788 4,419 3,621 3,512 2,452 2,483 2,963
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 16 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030
Average Load (aMW)–50 Percentile
Residential 914 838 729 616 547 589 865 701 573 577 702 1,024
Commercial 556 530 506 495 496 530 615 554 546 527 518 585
Irrigation 2 2 5 96 328 582 716 591 338 84 5 3
Industrial 381 377 379 360 352 387 383 388 384 395 389 373
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................169 159 146 142 157 190 238 205 167 142 145 182
System Load 2,147 2,029 1,883 1,825 1,986 2,381 2,927 2,548 2,115 1,836 1,878 2,290
Light Load 1,994 1,864 1,720 1,651 1,794 2,151 2,648 2,255 1,886 1,652 1,730 2,113
Heavy Load 2,268 2,153 2,012 1,951 2,137 2,565 3,147 2,759 2,316 1,969 1,997 2,442
Total Load 2,147 2,029 1,883 1,825 1,986 2,381 2,927 2,548 2,115 1,836 1,878 2,290
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,666 2,657 2,398 2,333 3,210 3,834 4,481 3,663 3,554 2,473 2,504 2,987
Total Peak Load 2,666 2,657 2,398 2,333 3,210 3,834 4,481 3,663 3,554 2,473 2,504 2,987

Monthly Summary1 1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031
Average Load (aMW)–50 Percentile
Residential 923 845 736 621 553 597 877 710 580 582 708 1,035
Commercial 561 534 510 499 500 535 620 559 552 532 523 591
Irrigation 2 2 5 97 329 584 719 593 339 84 5 3
Industrial 387 382 384 365 357 392 389 394 389 401 395 378
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................170 160 148 143 158 192 240 207 169 143 147 184
System Load 2,169 2,047 1,901 1,842 2,005 2,404 2,956 2,573 2,137 1,854 1,896 2,314
Light Load 2,014 1,880 1,736 1,666 1,811 2,172 2,674 2,277 1,905 1,668 1,747 2,135
Heavy Load 2,281 2,172 2,030 1,970 2,144 2,590 3,159 2,807 2,307 1,988 2,016 2,443
Total Load 2,169 2,047 1,901 1,842 2,005 2,404 2,956 2,573 2,137 1,854 1,896 2,314
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,685 2,672 2,414 2,349 3,244 3,877 4,540 3,703 3,594 2,493 2,521 3,009
Total Peak Load 2,685 2,672 2,414 2,349 3,244 3,877 4,540 3,703 3,594 2,493 2,521 3,009

Monthly Summary 1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032
Average Load (aMW)–50th Percentile
Residential 932 852 742 627 559 605 889 720 587 587 714 1,045
Commercial 566 538 514 503 505 540 626 564 558 537 528 597
Irrigation 2 2 5 97 330 586 721 595 340 84 6 3
Industrial 392 375 390 370 362 398 394 399 395 407 400 384
Additional Firm 125 118 117 116 106 103 110 110 108 111 117 123
Loss ................................172 160 149 144 160 194 242 209 170 145 148 186
System Load 2,189 2,045 1,917 1,858 2,023 2,426 2,983 2,598 2,158 1,871 1,913 2,338
Light Load 2,033 1,879 1,751 1,681 1,828 2,191 2,699 2,299 1,924 1,683 1,763 2,157
Heavy Load 2,302 2,181 2,037 1,987 2,177 2,598 3,189 2,833 2,329 2,019 2,024 2,468
Total Load 2,189 2,045 1,917 1,858 2,023 2,426 2,983 2,598 2,158 1,871 1,913 2,338
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,706 2,687 2,430 2,365 3,277 3,918 4,599 3,741 3,633 2,513 2,538 3,032
Total Peak Load 2,706 2,687 2,430 2,365 3,277 3,918 4,599 3,741 3,633 2,513 2,538 3,032
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 17
Monthly Summary 1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033
Average Load (aMW)–50 Percentile
Residential 941 859 749 633 566 613 902 730 594 593 721 1,056
Commercial 572 543 518 508 510 546 632 570 564 543 533 604
Irrigation 2 2 5 97 332 589 724 598 342 85 6 3
Industrial 398 394 396 376 367 404 400 405 401 413 406 389
Additional Firm 125 123 117 116 106 103 110 110 108 111 117 123
Loss ................................174 163 150 146 161 196 245 211 172 146 150 187
System Load 2,212 2,083 1,936 1,876 2,043 2,450 3,013 2,624 2,181 1,890 1,932 2,362
Light Load 2,054 1,914 1,768 1,697 1,846 2,213 2,726 2,322 1,945 1,700 1,780 2,180
Heavy Load 2,336 2,210 2,057 2,006 2,198 2,623 3,240 2,842 2,354 2,039 2,044 2,494
Total Load 2,212 2,083 1,936 1,876 2,043 2,450 3,013 2,624 2,181 1,890 1,932 2,362
Peak Load (MW)–90 Percentile
System Peak (1 hour) 2,728 2,704 2,448 2,383 3,312 3,963 4,659 3,782 3,674 2,534 2,557 3,055
Total Peak Load 2,728 2,704 2,448 2,383 3,312 3,963 4,659 3,782 3,674 2,534 2,557 3,055

Monthly Summary 1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034
Average Load (aMW)–50 Percentile
Residential 950 866 756 639 572 621 915 740 602 598 727 1,067
Commercial 577 547 523 513 515 552 638 576 571 548 538 610
Irrigation 2 2 5 98 333 591 727 600 343 85 6 3
Industrial 403 399 401 381 372 409 405 411 406 419 412 395
Additional Firm 124 122 117 115 106 102 110 110 107 110 116 122
Loss ................................176 164 152 147 163 198 247 213 174 147 151 189
System Load 2,233 2,100 1,953 1,893 2,061 2,473 3,042 2,650 2,203 1,907 1,950 2,387
Light Load 2,073 1,930 1,783 1,713 1,863 2,234 2,752 2,345 1,964 1,716 1,796 2,202
Heavy Load 2,359 2,229 2,075 2,037 2,205 2,648 3,271 2,870 2,377 2,058 2,062 2,532
Total Load 2,233 2,100 1,953 1,893 2,061 2,473 3,042 2,650 2,203 1,907 1,950 2,387
Peak Load (MW)–90th Percentile
System Peak (1 hour) 2,749 2,720 2,464 2,399 3,345 4,005 4,719 3,822 3,714 2,553 2,575 3,077
Total Peak Load 2,749 2,720 2,464 2,399 3,345 4,005 4,719 3,822 3,714 2,553 2,575 3,077
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 18 2015 Integrated Resource Plan—Appendix C
Annual Summary
2015 2016 2017 2018 2019 2020 2021 2022 2023 2024
Billed Sales (MWh)–50 Percentile
Residential 5,144,709 5,270,572 5,372,014 5,441,649 5,508,610 5,556,959 5,616,876 5,673,430 5,740,794 5,823,961
Commercial 4,076,100 4,144,898 4,182,636 4,212,195 4,247,398 4,285,793 4,327,161 4,369,098 4,410,017 4,452,065
Irrigation 1,863,039 1,902,156 1,915,919 1,918,336 1,913,727 1,924,815 1,937,547 1,941,972 1,944,197 1,953,855
Industrial 2,413,190 2,573,787 2,642,594 2,692,807 2,738,789 2,786,007 2,837,470 2,889,584 2,942,288 2,994,216
Additional Firm 880,500 901,900 905,900 909,500 909,600 920,600 922,700 957,500 986,600 1,006,800
System Sales................14,377,538 14,793,313 15,019,064 15,174,487 15,318,124 15,474,174 15,641,753 15,831,584 16,023,896 16,230,898
Total Sales 14,377,538 14,793,313 15,019,064 15,174,487 15,318,124 15,474,174 15,641,753 15,831,584 16,023,896 16,230,898
Generation Month Sales (MWh)–50 Percentile
Residential 5,154,280 5,295,641 5,377,433 5,446,875 5,512,460 5,579,744 5,621,345 5,678,710 5,747,258 5,849,294
Commercial 4,079,899 4,158,522 4,184,382 4,214,240 4,249,614 4,299,933 4,329,571 4,371,459 4,412,441 4,466,707
Irrigation 1,863,058 1,902,215 1,915,920 1,918,334 1,913,732 1,924,874 1,937,549 1,941,973 1,944,202 1,953,915
Industrial 2,426,435 2,579,462 2,646,735 2,696,599 2,742,683 2,790,251 2,841,768 2,893,931 2,946,571 2,998,631
Additional Firm 880,500 901,900 905,900 909,500 909,600 920,600 922,700 957,500 986,600 1,006,800
System Sales................14,404,172 14,837,741 15,030,370 15,185,549 15,328,090 15,515,403 15,652,934 15,843,573 16,037,072 16,275,347
Total Sales 14,404,172 14,837,741 15,030,370 15,185,549 15,328,090 15,515,403 15,652,934 15,843,573 16,037,072 16,275,347
Loss ................................1,244,160 1,278,960 1,294,764 1,307,629 1,319,635 1,335,210 1,346,414 1,360,666 1,375,528 1,395,261
Required Generation 15,648,332 16,116,700 16,325,134 16,493,178 16,647,725 16,850,613 16,999,348 17,204,238 17,412,599 17,670,608
Average Load (aMW)–50 Percentile
Residential 588 603 614 622 629 635 642 648 656 666
Commercial 466 473 478 481 485 490 494 499 504 509
Irrigation 213 217 219 219 218 219 221 222 222 222
Industrial 277 294 302 308 313 318 324 330 336 341
Additional Firm 101 103 103 104 104 105 105 109 113 115
Loss ................................142 146 148 149 151 152 154 155 157 159
System Load 1,786 1,835 1,864 1,883 1,900 1,918 1,941 1,964 1,988 2,012
Light Load 1,621 1,665 1,691 1,709 1,725 1,741 1,761 1,782 1,804 1,826
Heavy Load 1,916 1,968 2,000 2,020 2,038 2,057 2,081 2,106 2,133 2,157
Total Load 1,786 1,835 1,864 1,883 1,900 1,918 1,941 1,964 1,988 2,012
Peak Load (MW)–90 Percentile
System Peak (1 Hour) 3,537 3,630 3,696 3,752 3,805 3,862 3,922 3,981 4,041 4,105
Total Peak Load 3,537 3,630 3,696 3,752 3,805 3,862 3,922 3,981 4,041 4,105

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 19
2025 2026 2027 2028 2029 2030 2031 2032 2033 2034
Billed Sales (MWh)–50 Percentile
Residential 5,908,438 5,993,931 6,078,974 6,166,782 6,253,879 6,328,432 6,396,305 6,464,673 6,535,425 6,605,069
Commercial 4,495,518 4,538,294 4,579,379 4,623,210 4,669,570 4,713,503 4,755,847 4,800,838 4,849,140 4,896,765
Irrigation 1,966,693 1,979,082 1,990,214 2,000,471 2,012,334 2,022,468 2,031,444 2,038,333 2,047,116 2,054,980
Industrial 3,047,748 3,101,332 3,154,544 3,207,964 3,263,009 3,314,431 3,364,294 3,412,358 3,461,829 3,509,388
Additional Firm 1,006,800 1,004,100 1,004,100 998,800 998,800 1,004,100 1,004,100 998,800 998,800 993,500
System Sales................16,425,196 16,616,739 16,807,211 16,997,227 17,197,592 17,382,934 17,551,990 17,715,002 17,892,310 18,059,702
Total Sales 16,425,196 16,616,739 16,807,211 16,997,227 17,197,592 17,382,934 17,551,990 17,715,002 17,892,310 18,059,702
Generation Month Sales (MWh)–50 Percentile
Residential 5,915,091 6,000,558 6,085,816 6,193,260 6,259,745 6,333,805 6,401,722 6,490,712 6,540,950 6,610,536
Commercial 4,497,988 4,540,679 4,581,913 4,638,404 4,672,117 4,715,970 4,758,459 4,816,547 4,851,901 4,899,689
Irrigation 1,966,699 1,979,087 1,990,219 2,000,532 2,012,339 2,022,472 2,031,447 2,038,393 2,047,120 2,054,984
Industrial 3,052,167 3,105,721 3,158,950 3,212,504 3,267,250 3,318,543 3,368,258 3,416,438 3,465,751 3,513,496
Additional Firm 1,006,800 1,004,100 1,004,100 998,800 998,800 1,004,100 1,004,100 998,800 998,800 993,500
System Sales................16,438,745 16,630,145 16,820,998 17,043,500 17,210,252 17,394,891 17,563,986 17,760,890 17,904,522 18,072,204
Total Sales 16,438,745 16,630,145 16,820,998 17,043,500 17,210,252 17,394,891 17,563,986 17,760,890 17,904,522 18,072,204
Loss ................................1,409,006 1,425,605 1,441,996 1,461,742 1,475,765 1,491,301 1,505,731 1,523,214 1,535,214 1,549,909
Required Generation 17,847,751 18,055,750 18,262,994 18,505,242 18,686,016 18,886,192 19,069,716 19,284,105 19,439,736 19,622,113
Average Load (aMW)–50th Percentile
Residential 675 685 695 705 715 723 731 739 747 755
Commercial 513 518 523 528 533 538 543 548 554 559
Irrigation 225 226 227 228 230 231 232 232 234 235
Industrial 348 355 361 366 373 379 385 389 396 401
Additional Firm 115 115 115 114 114 115 115 114 114 113
Loss ................................161 163 165 166 168 170 172 173 175 177
System Load 2,037 2,061 2,085 2,107 2,133 2,156 2,177 2,195 2,219 2,240
Light Load 1,849 1,871 1,892 1,912 1,936 1,957 1,976 1,992 2,014 2,033
Heavy Load 2,185 2,210 2,236 2,260 2,288 2,312 2,328 2,347 2,373 2,396
Total Load 2,037 2,061 2,085 2,107 2,133 2,156 2,177 2,195 2,219 2,240
Peak Load (MW)–90 Percentile
System Peak (1 Hour) 4,168 4,231 4,293 4,355 4,419 4,481 4,540 4,599 4,659 4,719
Total Peak Load 4,168 4,231 4,293 4,355 4,419 4,481 4,540 4,599 4,659 4,719

Sales and Load Forecast Data Idaho Power Company
Page 20 2015 Integrated Resource Plan—Appendix C
70th Percentile Load Forecast
Monthly Summary 1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015
Average Load (aMW)–70 Percentile
Residential 781 730 622 519 460 491 698 565 472 492 606 863
Commercial 492 479 450 440 437 462 541 481 467 457 452 507
Irrigation 2 2 6 106 348 577 678 555 324 84 5 3
Industrial 277 274 276 262 256 281 279 282 279 288 283 285
Additional Firm 105 103 99 101 95 100 98 98 101 100 104 103
Loss ................................143 137 124 122 138 168 205 174 142 120 123 153
System Load 1,800 1,724 1,575 1,549 1,734 2,079 2,498 2,156 1,785 1,541 1,573 1,914
Light Load 1,672 1,584 1,438 1,402 1,567 1,878 2,260 1,908 1,591 1,387 1,449 1,766
Heavy Load 1,902 1,829 1,683 1,657 1,878 2,226 2,686 2,351 1,940 1,653 1,682 2,030
Total Load 1,800 1,724 1,575 1,549 1,734 2,079 2,498 2,156 1,785 1,541 1,573 1,914
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,330 2,400 2,128 2,027 2,682 3,163 3,576 3,029 2,901 2,133 2,233 2,625
Total Peak Load 2,330 2,400 2,128 2,027 2,682 3,163 3,576 3,029 2,901 2,133 2,233 2,625

Monthly Summary 1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016
Average Load (aMW)–70 Percentile
Residential 799 745 636 531 472 505 718 581 484 504 619 881
Commercial 500 486 457 447 444 470 550 489 475 465 459 514
Irrigation 2 2 6 108 355 588 692 567 331 85 6 3
Industrial 296 283 294 279 273 300 297 301 298 307 302 293
Additional Firm 110 105 105 104 97 94 101 101 99 101 105 109
Loss ................................147 139 127 125 142 172 210 179 145 123 126 156
System Load 1,854 1,761 1,624 1,594 1,782 2,128 2,568 2,218 1,833 1,585 1,617 1,954
Light Load 1,722 1,618 1,483 1,443 1,611 1,922 2,324 1,963 1,634 1,426 1,489 1,803
Heavy Load 1,968 1,867 1,726 1,705 1,930 2,279 2,779 2,403 1,992 1,711 1,719 2,073
Total Load 1,854 1,761 1,624 1,594 1,782 2,128 2,568 2,218 1,833 1,585 1,617 1,954
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,400 2,437 2,181 2,082 2,748 3,266 3,669 3,122 2,992 2,183 2,281 2,663
Total Peak Load 2,400 2,437 2,181 2,082 2,748 3,266 3,669 3,122 2,992 2,183 2,281 2,663

Monthly Summary 1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017
Average Load (aMW)–70 Percentile
Residential 814 758 647 540 481 516 734 594 494 512 630 894
Commercial 505 490 460 451 448 475 555 494 480 469 464 518
Irrigation 2 2 6 109 357 592 697 571 333 86 6 3
Industrial 304 300 302 287 280 308 305 309 306 315 310 299
Additional Firm 111 110 106 105 97 94 102 102 100 101 105 109
Loss ................................149 142 129 127 144 174 213 182 148 125 128 158
System Load 1,884 1,802 1,649 1,618 1,808 2,159 2,606 2,251 1,861 1,609 1,642 1,980
Light Load 1,750 1,656 1,506 1,464 1,634 1,950 2,358 1,992 1,659 1,448 1,513 1,827
Heavy Load 2,000 1,912 1,752 1,741 1,946 2,312 2,820 2,439 2,022 1,737 1,746 2,111
Total Load 1,884 1,802 1,649 1,618 1,808 2,159 2,606 2,251 1,861 1,609 1,642 1,980
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,426 2,472 2,204 2,103 2,788 3,320 3,736 3,172 3,042 2,209 2,305 2,686
Total Peak Load 2,426 2,472 2,204 2,103 2,788 3,320 3,736 3,172 3,042 2,209 2,305 2,686
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 21
Monthly Summary 1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018
Average Load (aMW)–70 Percentile
Residential 823 766 654 547 488 524 747 604 501 518 636 905
Commercial 508 492 463 454 452 478 559 498 485 473 467 523
Irrigation 2 2 6 109 357 593 698 571 334 86 6 3
Industrial 309 306 308 292 286 314 311 315 312 321 316 304
Additional Firm 112 110 106 105 98 94 102 102 100 102 106 110
Loss ................................151 144 130 128 145 176 215 183 149 126 129 160
System Load 1,906 1,821 1,667 1,635 1,826 2,180 2,631 2,274 1,880 1,626 1,660 2,003
Light Load 1,770 1,673 1,522 1,479 1,650 1,969 2,381 2,012 1,676 1,463 1,529 1,848
Heavy Load 2,013 1,931 1,771 1,759 1,965 2,334 2,847 2,463 2,059 1,744 1,765 2,136
Total Load 1,906 1,821 1,667 1,635 1,826 2,180 2,631 2,274 1,880 1,626 1,660 2,003
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,433 2,483 2,213 2,109 2,820 3,356 3,793 3,205 3,076 2,228 2,313 2,703
Total Peak Load 2,433 2,483 2,213 2,109 2,820 3,356 3,793 3,205 3,076 2,228 2,313 2,703

Monthly Summary 1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019
Average Load (aMW)–70 Percentile
Residential 833 774 661 553 495 533 759 614 508 523 643 913
Commercial 512 496 466 457 455 483 564 503 490 477 471 528
Irrigation 2 2 6 109 356 592 696 570 333 86 6 3
Industrial 315 311 313 297 291 319 316 320 317 327 321 309
Additional Firm 112 110 106 105 98 94 102 102 100 102 106 110
Loss ................................152 145 132 129 147 177 217 185 151 128 131 161
System Load 1,926 1,838 1,683 1,650 1,842 2,198 2,654 2,294 1,898 1,642 1,677 2,024
Light Load 1,789 1,689 1,537 1,493 1,664 1,985 2,401 2,030 1,692 1,478 1,545 1,867
Heavy Load 2,035 1,950 1,798 1,765 1,982 2,368 2,853 2,484 2,078 1,761 1,783 2,158
Total Load 1,926 1,838 1,683 1,650 1,842 2,198 2,654 2,294 1,898 1,642 1,677 2,024
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,456 2,500 2,231 2,127 2,849 3,387 3,847 3,234 3,108 2,246 2,332 2,723
Total Peak Load 2,456 2,500 2,231 2,127 2,849 3,387 3,847 3,234 3,108 2,246 2,332 2,723

Monthly Summary 1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020
Average Load (aMW)–70 Percentile
Residential 839 779 665 557 500 539 769 621 513 527 647 922
Commercial 517 500 470 461 460 487 569 507 495 482 475 533
Irrigation 2 2 6 109 358 595 700 573 335 86 6 3
Industrial 320 306 318 302 296 325 322 326 322 332 327 315
Additional Firm 113 108 107 107 99 96 103 103 101 103 107 111
Loss ................................154 145 133 130 148 179 219 187 152 129 132 163
System Load 1,946 1,839 1,700 1,667 1,860 2,221 2,681 2,318 1,919 1,659 1,693 2,047
Light Load 1,807 1,690 1,552 1,508 1,681 2,006 2,425 2,051 1,710 1,493 1,560 1,889
Heavy Load 2,055 1,950 1,816 1,782 2,015 2,378 2,882 2,528 2,085 1,779 1,811 2,171
Total Load 1,946 1,839 1,700 1,667 1,860 2,221 2,681 2,318 1,919 1,659 1,693 2,047
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,479 2,515 2,249 2,145 2,882 3,426 3,905 3,270 3,143 2,264 2,351 2,747
Total Peak Load 2,479 2,515 2,249 2,145 2,882 3,426 3,905 3,270 3,143 2,264 2,351 2,747
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 22 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021
Average Load (aMW)–70 Percentile
Residential 847 785 671 562 506 547 780 630 520 532 653 931
Commercial 522 504 474 465 464 493 574 513 501 486 480 539
Irrigation 2 2 6 110 360 599 704 577 337 87 6 3
Industrial 326 323 324 308 301 331 328 332 328 338 333 320
Additional Firm 113 112 108 107 99 96 103 103 101 103 107 112
Loss ................................155 147 134 132 150 181 221 189 154 130 133 165
System Load 1,967 1,873 1,717 1,684 1,880 2,245 2,710 2,344 1,940 1,677 1,711 2,070
Light Load 1,826 1,721 1,568 1,524 1,699 2,028 2,452 2,074 1,730 1,509 1,577 1,910
Heavy Load 2,088 1,987 1,824 1,801 2,036 2,404 2,914 2,557 2,109 1,810 1,819 2,195
Total Load 1,967 1,873 1,717 1,684 1,880 2,245 2,710 2,344 1,940 1,677 1,711 2,070
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,495 2,531 2,263 2,158 2,916 3,469 3,965 3,310 3,182 2,284 2,365 2,766
Total Peak Load 2,495 2,531 2,263 2,158 2,916 3,469 3,965 3,310 3,182 2,284 2,365 2,766

Monthly Summary 1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022
Average Load (aMW)–70 Percentile
Residential 855 791 677 567 512 554 791 639 526 536 658 941
Commercial 527 508 478 469 469 498 580 518 506 491 484 544
Irrigation 2 2 6 110 361 600 706 578 338 87 6 3
Industrial 332 329 330 314 307 337 334 338 334 345 339 326
Additional Firm 119 117 112 111 102 99 106 106 104 107 112 117
Loss ................................157 149 135 133 151 182 223 191 155 132 135 167
System Load 1,992 1,895 1,738 1,704 1,902 2,270 2,740 2,371 1,964 1,698 1,733 2,098
Light Load 1,850 1,741 1,587 1,542 1,718 2,050 2,479 2,098 1,751 1,527 1,597 1,936
Heavy Load 2,115 2,011 1,847 1,823 2,060 2,430 2,964 2,567 2,134 1,832 1,843 2,226
Total Load 1,992 1,895 1,738 1,704 1,902 2,270 2,740 2,371 1,964 1,698 1,733 2,098
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,513 2,550 2,281 2,173 2,952 3,510 4,026 3,348 3,221 2,307 2,383 2,792
Total Peak Load 2,513 2,550 2,281 2,173 2,952 3,510 4,026 3,348 3,221 2,307 2,383 2,792

Monthly Summary 1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023
Average Load (aMW)–70 Percentile
Residential 864 798 684 574 518 562 803 649 533 542 664 954
Commercial 532 512 482 473 473 503 585 523 512 496 489 550
Irrigation 2 2 6 110 361 600 707 579 338 87 6 3
Industrial 338 335 336 319 312 343 340 344 340 351 345 332
Additional Firm 123 121 116 114 105 102 109 109 107 110 115 121
Loss ................................159 151 137 134 153 184 226 193 157 133 136 169
System Load 2,019 1,918 1,760 1,725 1,923 2,294 2,769 2,397 1,987 1,719 1,755 2,128
Light Load 1,874 1,762 1,607 1,561 1,738 2,072 2,505 2,121 1,772 1,546 1,617 1,964
Heavy Load 2,143 2,035 1,870 1,857 2,070 2,457 2,996 2,596 2,159 1,855 1,866 2,270
Total Load 2,019 1,918 1,760 1,725 1,923 2,294 2,769 2,397 1,987 1,719 1,755 2,128
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,541 2,572 2,303 2,194 2,987 3,552 4,086 3,387 3,261 2,330 2,406 2,822
Total Peak Load 2,541 2,572 2,303 2,194 2,987 3,552 4,086 3,387 3,261 2,330 2,406 2,822
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 23
Monthly Summary 1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024
Average Load (aMW)–70 Percentile
Residential 876 808 692 581 527 572 817 661 541 548 672 967
Commercial 537 516 486 477 478 508 590 528 518 501 494 556
Irrigation 2 2 6 111 363 603 710 582 340 88 6 3
Industrial 344 329 342 325 318 349 346 350 346 357 351 338
Additional Firm 126 119 118 117 107 104 111 111 109 112 118 124
Loss ................................161 151 139 136 154 186 228 195 159 135 138 171
System Load 2,046 1,925 1,783 1,747 1,947 2,322 2,803 2,427 2,013 1,741 1,778 2,159
Light Load 1,900 1,769 1,628 1,581 1,759 2,097 2,536 2,148 1,794 1,566 1,638 1,992
Heavy Load 2,161 2,041 1,904 1,869 2,095 2,502 3,014 2,629 2,204 1,867 1,891 2,302
Total Load 2,046 1,925 1,783 1,747 1,947 2,322 2,803 2,427 2,013 1,741 1,778 2,159
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,573 2,596 2,328 2,218 3,025 3,600 4,151 3,431 3,305 2,354 2,433 2,853
Total Peak Load 2,573 2,596 2,328 2,218 3,025 3,600 4,151 3,431 3,305 2,354 2,433 2,853

Monthly Summary 1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025
Average Load (aMW)–70 Percentile
Residential 887 817 701 589 535 582 832 672 550 555 680 981
Commercial 542 520 490 482 483 513 596 534 524 506 499 561
Irrigation 2 2 6 111 365 607 715 586 342 88 6 3
Industrial 350 347 348 331 323 355 352 357 353 364 358 344
Additional Firm 126 124 118 117 107 104 111 111 109 112 118 124
Loss ................................163 154 140 138 156 189 231 198 161 136 140 173
System Load 2,071 1,964 1,803 1,767 1,969 2,349 2,837 2,457 2,037 1,761 1,799 2,186
Light Load 1,923 1,804 1,647 1,599 1,779 2,122 2,567 2,174 1,817 1,585 1,658 2,017
Heavy Load 2,188 2,084 1,926 1,890 2,119 2,531 3,050 2,679 2,214 1,889 1,924 2,319
Total Load 2,071 1,964 1,803 1,767 1,969 2,349 2,837 2,457 2,037 1,761 1,799 2,186
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,601 2,617 2,350 2,240 3,062 3,648 4,215 3,476 3,349 2,377 2,456 2,880
Total Peak Load 2,601 2,617 2,350 2,240 3,062 3,648 4,215 3,476 3,349 2,377 2,456 2,880

Monthly Summary 1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026
Average Load (aMW)–70 Percentile
Residential 899 827 709 597 543 592 847 684 558 562 688 994
Commercial 547 524 494 486 487 518 602 539 530 511 503 567
Irrigation 2 2 6 112 367 610 719 589 344 89 6 3
Industrial 356 353 354 337 329 362 358 363 359 370 364 350
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................165 156 142 139 158 191 234 200 163 138 141 176
System Load 2,095 1,985 1,823 1,787 1,991 2,376 2,871 2,486 2,062 1,781 1,820 2,213
Light Load 1,946 1,824 1,665 1,617 1,799 2,146 2,597 2,200 1,838 1,603 1,677 2,042
Heavy Load 2,214 2,106 1,948 1,911 2,157 2,544 3,086 2,712 2,241 1,911 1,946 2,348
Total Load 2,095 1,985 1,823 1,787 1,991 2,376 2,871 2,486 2,062 1,781 1,820 2,213
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,627 2,637 2,370 2,261 3,099 3,697 4,278 3,521 3,393 2,399 2,479 2,906
Total Peak Load 2,627 2,637 2,370 2,261 3,099 3,697 4,278 3,521 3,393 2,399 2,479 2,906
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 24 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027
Average Load (aMW)–70 Percentile
Residential 910 836 718 604 551 602 862 697 567 569 696 1,008
Commercial 552 528 498 490 492 524 607 544 535 516 508 573
Irrigation 2 2 6 112 369 614 723 592 346 89 6 3
Industrial 363 359 360 342 335 368 364 369 365 376 370 356
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................167 157 143 141 160 193 236 202 165 139 143 178
System Load 2,120 2,006 1,843 1,806 2,013 2,403 2,904 2,515 2,086 1,801 1,840 2,241
Light Load 1,969 1,843 1,683 1,635 1,819 2,170 2,627 2,226 1,860 1,621 1,696 2,068
Heavy Load 2,250 2,129 1,959 1,932 2,180 2,573 3,122 2,743 2,267 1,944 1,957 2,377
Total Load 2,120 2,006 1,843 1,806 2,013 2,403 2,904 2,515 2,086 1,801 1,840 2,241
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,653 2,656 2,391 2,281 3,136 3,744 4,341 3,565 3,437 2,422 2,500 2,932
Total Peak Load 2,653 2,656 2,391 2,281 3,136 3,744 4,341 3,565 3,437 2,422 2,500 2,932

Monthly Summary 1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028
Average Load (aMW)–70 Percentile
Residential 922 846 727 612 560 612 877 709 576 576 705 1,022
Commercial 558 532 502 494 497 529 613 550 541 521 513 579
Irrigation 2 2 6 113 371 617 727 595 347 89 6 3
Industrial 369 352 367 348 340 374 371 375 371 383 376 362
Additional Firm 125 118 117 116 106 103 110 110 108 111 117 123
Loss ................................169 158 145 142 161 195 239 205 167 141 144 180
System Load 2,145 2,010 1,864 1,826 2,035 2,429 2,937 2,544 2,111 1,822 1,861 2,268
Light Load 1,991 1,846 1,702 1,652 1,839 2,194 2,657 2,251 1,882 1,639 1,714 2,093
Heavy Load 2,276 2,130 1,980 1,965 2,190 2,601 3,177 2,755 2,294 1,966 1,979 2,419
Total Load 2,145 2,010 1,864 1,826 2,035 2,429 2,937 2,544 2,111 1,822 1,861 2,268
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,680 2,675 2,412 2,303 3,172 3,792 4,404 3,609 3,481 2,444 2,523 2,960
Total Peak Load 2,680 2,675 2,412 2,303 3,172 3,792 4,404 3,609 3,481 2,444 2,523 2,960

Monthly Summary 1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029
Average Load (aMW)–70 Percentile
Residential 934 856 736 620 568 622 893 721 585 583 713 1,034
Commercial 563 537 506 499 502 535 619 556 548 526 518 585
Irrigation 2 2 6 113 372 620 731 599 349 90 6 3
Industrial 375 371 373 354 346 381 377 382 378 389 383 367
Additional Firm 125 123 117 116 106 103 110 110 108 111 117 123
Loss ................................171 161 147 144 163 197 242 207 169 143 146 182
System Load 2,170 2,050 1,885 1,847 2,058 2,457 2,972 2,575 2,136 1,843 1,883 2,294
Light Load 2,015 1,883 1,721 1,671 1,860 2,220 2,688 2,279 1,905 1,658 1,734 2,117
Heavy Load 2,293 2,174 2,002 1,987 2,215 2,631 3,215 2,789 2,339 1,976 2,002 2,447
Total Load 2,170 2,050 1,885 1,847 2,058 2,457 2,972 2,575 2,136 1,843 1,883 2,294
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,708 2,697 2,434 2,325 3,210 3,842 4,469 3,655 3,527 2,468 2,546 2,985
Total Peak Load 2,708 2,697 2,434 2,325 3,210 3,842 4,469 3,655 3,527 2,468 2,546 2,985
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 25
Monthly Summary 1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030
Average Load (aMW)–70 Percentile
Residential 944 864 743 627 575 631 907 732 593 589 720 1,045
Commercial 568 541 511 503 507 540 625 561 554 532 523 591
Irrigation 2 2 6 114 374 623 734 602 351 90 6 3
Industrial 381 377 379 360 352 387 383 388 384 395 389 373
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................173 162 148 145 165 199 245 209 171 144 148 184
System Load 2,194 2,070 1,904 1,866 2,080 2,483 3,004 2,603 2,160 1,862 1,902 2,320
Light Load 2,037 1,902 1,739 1,688 1,879 2,243 2,717 2,304 1,926 1,675 1,753 2,141
Heavy Load 2,318 2,196 2,034 1,995 2,238 2,676 3,229 2,819 2,365 1,997 2,023 2,474
Total Load 2,194 2,070 1,904 1,866 2,080 2,483 3,004 2,603 2,160 1,862 1,902 2,320
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,732 2,715 2,453 2,344 3,246 3,888 4,531 3,698 3,569 2,489 2,567 3,009
Total Peak Load 2,732 2,715 2,453 2,344 3,246 3,888 4,531 3,698 3,569 2,489 2,567 3,009

Monthly Summary 1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031
Average Load (aMW)–70 Percentile
Residential 953 871 750 633 582 640 919 743 600 594 726 1,056
Commercial 573 545 514 508 511 545 630 567 560 537 528 597
Irrigation 2 2 6 114 376 626 738 604 353 91 6 3
Industrial 387 382 384 365 357 392 389 394 389 401 395 378
Additional Firm 126 123 118 116 107 103 111 110 108 112 118 124
Loss ................................175 164 149 147 166 201 247 211 173 145 149 186
System Load 2,216 2,088 1,922 1,883 2,099 2,507 3,033 2,629 2,182 1,880 1,920 2,344
Light Load 2,057 1,918 1,755 1,704 1,897 2,265 2,744 2,327 1,945 1,691 1,769 2,163
Heavy Load 2,330 2,215 2,053 2,014 2,246 2,702 3,242 2,868 2,355 2,016 2,042 2,474
Total Load 2,216 2,088 1,922 1,883 2,099 2,507 3,033 2,629 2,182 1,880 1,920 2,344
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,751 2,730 2,469 2,359 3,280 3,931 4,592 3,737 3,608 2,509 2,584 3,031
Total Peak Load 2,751 2,730 2,469 2,359 3,280 3,931 4,592 3,737 3,608 2,509 2,584 3,031

Monthly Summary 1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032
Average Load (aMW)–70 Percentile
Residential 962 878 756 639 589 648 932 753 607 600 732 1,067
Commercial 579 549 519 512 516 551 636 572 566 542 533 603
Irrigation 2 2 6 115 377 627 740 606 354 91 6 3
Industrial 392 375 390 370 362 398 394 399 395 407 400 384
Additional Firm 125 118 117 116 106 103 110 110 108 111 117 123
Loss ................................176 164 151 148 168 203 249 214 174 147 150 188
System Load 2,236 2,087 1,939 1,900 2,118 2,530 3,062 2,654 2,203 1,897 1,938 2,367
Light Load 2,076 1,917 1,770 1,719 1,914 2,286 2,770 2,349 1,965 1,707 1,785 2,185
Heavy Load 2,352 2,224 2,060 2,032 2,280 2,709 3,273 2,895 2,378 2,047 2,050 2,499
Total Load 2,236 2,087 1,939 1,900 2,118 2,530 3,062 2,654 2,203 1,897 1,938 2,367
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,772 2,745 2,486 2,375 3,313 3,972 4,651 3,776 3,647 2,529 2,601 3,054
Total Peak Load 2,772 2,745 2,486 2,375 3,313 3,972 4,651 3,776 3,647 2,529 2,601 3,054
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Sales and Load Forecast Data Idaho Power Company
Page 26 2015 Integrated Resource Plan—Appendix C
Monthly Summary 1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033
Average Load (aMW)–70 Percentile
Residential 971 885 763 645 596 657 946 764 614 605 738 1,078
Commercial 584 554 523 517 522 557 642 578 572 547 538 609
Irrigation 2 2 6 115 378 630 743 609 355 91 6 3
Industrial 398 394 396 376 367 404 400 405 401 413 406 389
Additional Firm 125 123 117 116 106 103 110 110 108 111 117 123
Loss ................................178 167 152 149 170 205 252 216 176 148 152 190
System Load 2,259 2,124 1,957 1,918 2,139 2,556 3,093 2,682 2,227 1,916 1,957 2,392
Light Load 2,097 1,952 1,787 1,735 1,933 2,308 2,798 2,373 1,985 1,724 1,803 2,208
Heavy Load 2,386 2,254 2,079 2,051 2,302 2,736 3,325 2,905 2,403 2,068 2,070 2,525
Total Load 2,259 2,124 1,957 1,918 2,139 2,556 3,093 2,682 2,227 1,916 1,957 2,392
Peak Load (MW)–95 Percentile
System Peak (1 hour) 2,794 2,763 2,504 2,393 3,348 4,017 4,713 3,817 3,688 2,549 2,620 3,077
Total Peak Load 2,794 2,763 2,504 2,393 3,348 4,017 4,713 3,817 3,688 2,549 2,620 3,077

Monthly Summary 1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034
Average Load (aMW)–70 Percentile
Residential 980 892 769 651 603 666 959 774 622 610 744 1,089
Commercial 590 559 528 521 527 563 648 584 579 553 543 616
Irrigation 2 2 6 115 379 632 746 611 356 92 6 3
Industrial 403 399 401 381 372 409 405 411 406 419 412 395
Additional Firm 124 122 117 115 106 102 110 110 107 110 116 122
Loss ................................180 168 153 151 171 207 254 218 178 150 153 192
System Load 2,280 2,142 1,974 1,935 2,159 2,579 3,123 2,708 2,249 1,934 1,974 2,416
Light Load 2,117 1,968 1,803 1,751 1,950 2,330 2,825 2,396 2,005 1,740 1,819 2,230
Heavy Load 2,409 2,273 2,098 2,082 2,309 2,762 3,357 2,933 2,427 2,087 2,088 2,563
Total Load 2,280 2,142 1,974 1,935 2,159 2,579 3,123 2,708 2,249 1,934 1,974 2,416
Peak Load (MW)–95th Percentile
System Peak (1 hour) 2,815 2,778 2,520 2,409 3,382 4,060 4,773 3,857 3,728 2,569 2,638 3,100
Total Peak Load 2,815 2,778 2,520 2,409 3,382 4,060 4,773 3,857 3,728 2,569 2,638 3,100
1 The sales and load forecast considers and reflects the impact of existing energy efficiency programs on average load and peak demand. The new energy efficiency programs, proposed as part of the 2015 IRP, are accounted for in the load and resource balance. The peak load forecast does not include the impact of existing or new demand response programs, which are both accounted for in the load and resource balance.

Idaho Power Company Sales and Load Forecast Data
2015 Integrated Resource Plan—Appendix C Page 27
Annual Summary
2015 2016 2017 2018 2019 2020 2021 2022 2023 2024
Billed Sales (MWh)–70 Percentile
Residential 5,317,055 5,447,177 5,552,704 5,625,914 5,695,969 5,747,179 5,809,857 5,869,137 5,939,209 6,025,044
Commercial 4,131,001 4,201,012 4,239,992 4,270,776 4,307,093 4,346,536 4,388,927 4,431,884 4,473,825 4,516,895
Irrigation 1,977,605 2,016,722 2,030,485 2,032,902 2,028,293 2,039,381 2,052,113 2,056,538 2,058,763 2,068,421
Industrial 2,413,190 2,573,787 2,642,594 2,692,807 2,738,789 2,786,007 2,837,470 2,889,584 2,942,288 2,994,216
Additional Firm 880,500 901,900 905,900 909,500 909,600 920,600 922,700 957,500 986,600 1,006,800
System Sales................14,719,352 15,140,599 15,371,675 15,531,900 15,679,743 15,839,703 16,011,067 16,204,643 16,400,686 16,611,376
Total Sales 14,719,352 15,140,599 15,371,675 15,531,900 15,679,743 15,839,703 16,011,067 16,204,643 16,400,686 16,611,376
Generation Month Sales (MWh)–70 Percentile
Residential 5,326,729 5,472,945 5,558,208 5,631,202 5,699,862 5,770,615 5,814,359 5,874,448 5,945,701 6,051,025
Commercial 4,134,835 4,214,880 4,241,773 4,272,855 4,309,340 4,360,932 4,391,367 4,434,274 4,476,279 4,531,807
Irrigation 1,977,624 2,016,781 2,030,486 2,032,900 2,028,299 2,039,440 2,052,115 2,056,539 2,058,768 2,068,481
Industrial 2,426,435 2,579,462 2,646,735 2,696,599 2,742,683 2,790,251 2,841,768 2,893,931 2,946,571 2,998,631
Additional Firm 880,500 901,900 905,900 909,500 909,600 920,600 922,700 957,500 986,600 1,006,800
System Sales................14,746,123 15,185,968 15,383,103 15,543,056 15,689,784 15,881,839 16,022,310 16,216,691 16,413,918 16,656,744
Total Sales 14,746,123 15,185,968 15,383,103 15,543,056 15,689,784 15,881,839 16,022,310 16,216,691 16,413,918 16,656,744
Loss ................................1,276,987 1,312,390 1,328,626 1,341,950 1,354,358 1,370,388 1,381,874 1,396,485 1,411,705 1,431,876
Required Generation 16,023,110 16,498,358 16,711,729 16,885,006 17,044,142 17,252,227 17,404,184 17,613,176 17,825,623 18,088,620
Average Load (aMW)–70 Percentile
Residential 608 623 634 643 651 657 664 671 679 689
Commercial 472 480 484 488 492 496 501 506 511 516
Irrigation 226 230 232 232 232 232 234 235 235 235
Industrial 277 294 302 308 313 318 324 330 336 341
Additional Firm 101 103 103 104 104 105 105 109 113 115
Loss ................................146 149 152 153 155 156 158 159 161 163
System Load 1,829 1,878 1,908 1,928 1,946 1,964 1,987 2,011 2,035 2,059
Light Load 1,660 1,705 1,731 1,749 1,766 1,782 1,803 1,825 1,847 1,869
Heavy Load 1,962 2,014 2,047 2,068 2,087 2,106 2,131 2,157 2,183 2,208
Total Load 1,829 1,878 1,908 1,928 1,946 1,964 1,987 2,011 2,035 2,059
Peak Load (MW)–95 Percentile
System Peak (1 Hour) 3,576 3,669 3,736 3,793 3,847 3,905 3,965 4,026 4,086 4,151
Total Peak Load 3,576 3,669 3,736 3,793 3,847 3,905 3,965 4,026 4,086 4,151

Sales and Load Forecast Data Idaho Power Company
Page 28 2015 Integrated Resource Plan—Appendix C
2025 2026 2027 2028 2029 2030 2031 2032 2033 2034
Billed Sales (MWh)–70 Percentile
Residential 6,112,140 6,200,195 6,287,755 6,378,017 6,467,506 6,544,386 6,614,509 6,685,063 6,757,939 6,829,662
Commercial 4,561,364 4,605,150 4,647,240 4,692,068 4,739,417 4,784,329 4,827,637 4,873,585 4,922,833 4,971,401
Irrigation 2,081,259 2,093,648 2,104,780 2,115,037 2,126,900 2,137,034 2,146,010 2,152,899 2,161,682 2,169,546
Industrial 3,047,748 3,101,332 3,154,544 3,207,964 3,263,009 3,314,431 3,364,294 3,412,358 3,461,829 3,509,388
Additional Firm 1,006,800 1,004,100 1,004,100 998,800 998,800 1,004,100 1,004,100 998,800 998,800 993,500
System Sales................16,809,311 17,004,425 17,198,419 17,391,886 17,595,632 17,784,280 17,956,550 18,122,705 18,303,083 18,473,496
Total Sales 16,809,311 17,004,425 17,198,419 17,391,886 17,595,632 17,784,280 17,956,550 18,122,705 18,303,083 18,473,496
Generation Month Sales (MWh)–70 Percentile
Residential 6,118,814 6,206,840 6,294,611 6,405,135 6,473,380 6,549,762 6,619,925 6,711,729 6,763,457 6,835,118
Commercial 4,563,863 4,607,563 4,649,803 4,707,547 4,741,992 4,786,824 4,830,276 4,889,591 4,925,621 4,974,352
Irrigation 2,081,265 2,093,654 2,104,785 2,115,098 2,126,905 2,137,039 2,146,014 2,152,960 2,161,686 2,169,550
Industrial 3,052,167 3,105,721 3,158,950 3,212,504 3,267,250 3,318,543 3,368,258 3,416,438 3,465,751 3,513,496
Additional Firm 1,006,800 1,004,100 1,004,100 998,800 998,800 1,004,100 1,004,100 998,800 998,800 993,500
System Sales................16,822,910 17,017,877 17,212,249 17,439,084 17,608,327 17,796,269 17,968,573 18,169,518 18,315,315 18,486,015
Total Sales 16,822,910 17,017,877 17,212,249 17,439,084 17,608,327 17,796,269 17,968,573 18,169,518 18,315,315 18,486,015
Loss ................................1,445,886 1,462,827 1,479,556 1,499,718 1,513,980 1,529,833 1,544,571 1,562,443 1,574,650 1,589,634
Required Generation 18,268,795 18,480,705 18,691,805 18,938,803 19,122,307 19,326,102 19,513,144 19,731,961 19,889,966 20,075,650
Average Load (aMW)–70th Percentile
Residential 698 709 719 729 739 748 756 764 772 780
Commercial 521 526 531 536 541 546 551 557 562 568
Irrigation 238 239 240 241 243 244 245 245 247 248
Industrial 348 355 361 366 373 379 385 389 396 401
Additional Firm 115 115 115 114 114 115 115 114 114 113
Loss ................................165 167 169 171 173 175 176 178 180 181
System Load 2,085 2,110 2,134 2,156 2,183 2,206 2,228 2,246 2,271 2,292
Light Load 1,893 1,915 1,936 1,957 1,981 2,002 2,022 2,039 2,061 2,080
Heavy Load 2,237 2,263 2,288 2,313 2,342 2,366 2,382 2,402 2,428 2,452
Total Load 2,085 2,110 2,134 2,156 2,183 2,206 2,228 2,246 2,271 2,292
Peak Load (MW)–95th Percentile
System Peak (1 Hour) 4,215 4,278 4,341 4,404 4,469 4,531 4,592 4,651 4,713 4,773
Total Peak Load 4,215 4,278 4,341 4,404 4,469 4,531 4,592 4,651 4,713 4,773

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 29
LOAD AND RESOURCE BALANCE DATA
Monthly Average Energy Load and Resource Balance
1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015
Forecast EE 11 11 11 11 13 15 16 15 12 10 10 11
Load Forecast (70th% w/EE) (1,800) (1,724) (1,575) (1,549) (1,734) (2,079) (2,498) (2,156) (1,785) (1,541) (1,573) (1,914)
Total non-forecasted trended EE 0 0 0 0 0 0 0 0 0 0 0 0
Net Load Forecast (70 % w/ EE) (1,800) (1,724) (1,575) (1,549) (1,734) (2,079) (2,498) (2,156) (1,785) (1,541) (1,573) (1,914)
Existing Resources
Total Coal 960 960 933 777 867 960 960 960 812 789 936 960
Total Gas 516 286 280 281 279 516 496 515 277 281 284 525
Hydro (70th%)—HCC 569 702 591 720 873 601 526 369 455 407 343 483
Hydro (70th%)—Other 217 291 237 263 314 328 279 210 224 219 202 208
Sho-Ban Water Lease 0 0 0 0 0 0 71 0 0 0 0 0
Total Hydro (70 %) 786 994 828 983 1,187 929 876 580 679 626 545 691
CSPP (PURPA) 202 244 248 303 299 301 258 219 241 223 205 198
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 5 6 7 9 10 11 10 7 4 1 3 4
Clatskanie Exchange—Return 0 0 (20) (20) 0 0 0 0 0 (20) (20) 0
Total PPAs 76 73 54 49 62 65 62 61 55 36 46 74
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 2,538 2,556 2,342 2,393 2,694 2,771 2,651 2,334 2,063 1,955 2,015 2,447
Monthly Surplus/Deficit 738 832 767 844 960 692 153 178 278 414 442 534
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 738 832 767 844 960 692 153 178 278 414 442 534

Load and Resource Balance Data Idaho Power Company
Page 30 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016
Forecast EE 19 18 18 18 21 23 24 23 19 17 17 18
Load Forecast (70th% w/EE) (1,854) (1,761) (1,624) (1,594) (1,782) (2,128) (2,568) (2,218) (1,833) (1,585) (1,617) (1,954)
Total non-forecasted trended EE 7 7 7 7 8 9 9 9 7 7 7 7
Net Load Forecast (70 % w/ EE) (1,847) (1,754) (1,618) (1,587) (1,775) (2,120) (2,559) (2,209) (1,825) (1,579) (1,610) (1,947)
Existing Resources
Total Coal 958 958 725 607 735 958 958 958 799 788 945 958
Total Gas 516 286 280 281 279 516 496 515 277 281 284 516
Hydro (70th%)—HCC 570 713 596 728 883 606 525 369 453 406 344 483
Hydro (70th%)—Other 218 307 243 265 316 328 279 210 224 219 202 208
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 787 1,019 839 994 1,198 934 804 579 677 625 545 690
CSPP (PURPA) 208 253 258 315 313 316 304 263 277 251 221 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 2,539 2,583 2,168 2,257 2,578 2,779 2,614 2,369 2,080 1,999 2,058 2,493
Monthly Surplus/Deficit 692 829 551 670 803 659 55 159 255 421 448 546
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 692 829 551 670 803 659 55 159 255 421 448 546

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 31
Monthly Average Energy Load and Resource Balance (continued)
1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017
Forecast EE 24 24 23 23 26 28 30 29 24 22 22 24
Load Forecast (70th% w/EE) (1,884) (1,802) (1,649) (1,618) (1,808) (2,159) (2,606) (2,251) (1,861) (1,609) (1,642) (1,980)
Total non-forecasted trended EE 19 19 18 18 20 22 24 22 19 17 17 19
Net Load Forecast (70 % w/ EE) (1,865) (1,784) (1,632) (1,600) (1,788) (2,137) (2,583) (2,229) (1,842) (1,592) (1,625) (1,961)
Existing Resources
Total Coal 958 958 926 751 754 958 958 958 958 958 958 958
Total Gas 525 286 280 281 279 507 505 515 277 281 284 516
Hydro (70th%)—HCC 567 710 601 731 895 614 526 370 449 407 343 486
Hydro (70th%)—Other 215 311 240 268 318 329 279 211 224 219 193 203
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 782 1,021 841 999 1,213 943 805 581 673 626 536 689
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 2,598 2,671 2,485 2,546 2,770 2,949 2,773 2,507 2,352 2,263 2,121 2,492
Monthly Surplus/Deficit 733 888 854 946 982 812 191 278 511 671 496 531
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 733 888 854 946 982 812 191 278 511 671 496 531

Load and Resource Balance Data Idaho Power Company
Page 32 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018
Forecast EE 32 31 29 31 36 41 43 41 33 29 29 31
Load Forecast (70th% w/EE) (1,906) (1,821) (1,667) (1,635) (1,826) (2,180) (2,631) (2,274) (1,880) (1,626) (1,660) (2,003)
Total non-forecasted trended EE 29 29 27 28 33 37 40 37 31 26 26 29
Net Load Forecast (70 % w/ EE) (1,876) (1,792) (1,640) (1,606) (1,793) (2,142) (2,592) (2,237) (1,850) (1,600) (1,633) (1,974)
Existing Resources
Total Coal 958 958 893 738 784 958 958 958 958 958 957 958
Total Gas 525 286 280 281 279 507 505 506 277 281 284 525
Hydro (70th%)—HCC 567 710 600 733 900 612 525 369 447 408 343 485
Hydro (70th%)—Other 216 309 234 270 319 329 279 211 224 220 192 200
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 783 1,019 834 1,003 1,219 941 804 580 671 628 535 685
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 2,599 2,669 2,445 2,537 2,806 2,947 2,772 2,497 2,350 2,264 2,120 2,497
Monthly Surplus/Deficit 722 877 806 931 1,013 805 180 260 500 664 486 522
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 722 877 806 931 1,013 805 180 260 500 664 486 522

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 33
Monthly Average Energy Load and Resource Balance (continued)
1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019
Forecast EE 39 38 36 37 43 48 51 48 40 34 35 38
Load Forecast (70th% w/EE) (1,926) (1,838) (1,683) (1,650) (1,842) (2,198) (2,654) (2,294) (1,898) (1,642) (1,677) (2,024)
Total non-forecasted trended EE 41 40 38 40 47 52 55 52 43 37 37 40
Net Load Forecast (70 % w/ EE) (1,885) (1,798) (1,645) (1,610) (1,795) (2,146) (2,598) (2,242) (1,855) (1,606) (1,640) (1,983)
Existing Resources
Total Coal 956 956 909 838 733 956 956 956 956 956 956 956
Total Gas 525 286 280 281 279 516 505 506 277 281 284 525
Hydro (70th%)—HCC 569 711 600 735 907 616 526 370 442 409 344 479
Hydro (70th%)—Other 215 302 221 263 321 330 280 211 224 221 186 193
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 784 1,012 821 998 1,227 946 806 581 666 629 530 671
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 2,598 2,660 2,448 2,632 2,764 2,959 2,773 2,497 2,343 2,264 2,113 2,481
Monthly Surplus/Deficit 713 863 802 1,021 969 814 175 255 488 659 473 498
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 713 863 802 1,021 969 814 175 255 488 659 473 498

Load and Resource Balance Data Idaho Power Company
Page 34 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020
Forecast EE 48 47 44 47 54 61 66 62 50 43 43 47
Load Forecast (70th% w/EE) (1,946) (1,839) (1,700) (1,667) (1,860) (2,221) (2,681) (2,318) (1,919) (1,659) (1,693) (2,047)
Total non-forecasted trended EE 47 45 43 45 53 59 64 60 48 42 42 45
Net Load Forecast (70 % w/ EE) (1,899) (1,794) (1,657) (1,622) (1,808) (2,161) (2,617) (2,258) (1,870) (1,618) (1,652) (2,001)
Existing Resources
Total Coal 807 786 54 54 337 811 851 807 781 348 394 807
Total Gas 494 145 87 – 87 510 494 512 135 – 90 503
Hydro (70th%)—HCC 566 709 600 733 905 614 525 369 436 409 344 472
Hydro (70th%)—Other 213 291 218 261 320 329 279 210 222 220 186 193
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 779 1,000 818 994 1,224 943 804 579 658 628 529 665
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 259 58 0 0 0 0 0 243 295 0
Existing Resource Subtotal 2,413 2,336 1,657 1,622 2,173 2,804 2,655 2,351 2,018 1,618 1,652 2,304
Monthly Surplus/Deficit 514 542 0 0 365 643 38 93 148 0 0 303
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 514 542 0 0 365 643 38 93 148 0 0 303

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 35
Monthly Average Energy Load and Resource Balance (continued)
1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021
Forecast EE 55 54 51 54 63 71 76 71 58 49 50 54
Load Forecast (70th% w/EE) (1,967) (1,873) (1,717) (1,684) (1,880) (2,245) (2,710) (2,344) (1,940) (1,677) (1,711) (2,070)
Total non-forecasted trended EE 55 53 51 53 62 70 75 70 57 49 49 53
Net Load Forecast (70 % w/ EE) (1,912) (1,820) (1,666) (1,631) (1,819) (2,175) (2,636) (2,274) (1,884) (1,628) (1,662) (2,016)
Existing Resources
Total Coal 753 732 – – 283 756 797 753 726 294 407 753
Total Gas 494 145 87 – 87 510 494 512 135 – 90 494
Hydro (70th%)—HCC 564 707 589 731 903 611 524 367 430 409 344 469
Hydro (70th%)—Other 211 285 208 259 319 328 278 209 221 219 185 192
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 775 992 797 990 1,222 939 802 576 651 627 529 661
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 345 126 0 0 37 0 0 309 293 0
Existing Resource Subtotal 2,355 2,274 1,666 1,631 2,116 2,746 2,636 2,294 1,957 1,628 1,662 2,237
Monthly Surplus/Deficit 443 455 0 0 297 571 0 20 73 0 0 221
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 443 455 0 0 297 571 0 20 73 0 0 221

Load and Resource Balance Data Idaho Power Company
Page 36 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022
Forecast EE 62 60 57 60 70 79 85 79 64 55 56 60
Load Forecast (70th% w/EE) (1,992) (1,895) (1,738) (1,704) (1,902) (2,270) (2,740) (2,371) (1,964) (1,698) (1,733) (2,098)
Total non-forecasted trended EE 64 63 60 62 73 82 88 82 67 57 58 63
Net Load Forecast (70 % w/ EE) (1,928) (1,833) (1,679) (1,642) (1,829) (2,188) (2,652) (2,288) (1,897) (1,640) (1,675) (2,035)
Existing Resources
Total Coal 753 732 – – 283 756 797 753 726 294 371 753
Total Gas 503 145 87 – 87 510 494 512 135 – 90 494
Hydro (70th%)—HCC 562 705 587 728 901 608 522 366 425 409 343 467
Hydro (70th%)—Other 210 286 203 257 318 327 278 208 220 218 184 191
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 771 991 790 986 1,219 935 800 574 645 627 528 658
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 363 142 0 0 56 0 0 322 344 0
Existing Resource Subtotal 2,360 2,273 1,679 1,642 2,113 2,743 2,652 2,292 1,950 1,640 1,675 2,234
Monthly Surplus/Deficit 433 441 0 0 284 555 0 3 53 0 (0) 199
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 433 441 0 0 284 555 0 3 53 0 (0) 199

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 37
Monthly Average Energy Load and Resource Balance (continued)
1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023
Forecast EE 68 67 63 66 77 87 93 87 71 61 61 67
Load Forecast (70th% w/EE) (2,019) (1,918) (1,760) (1,725) (1,923) (2,294) (2,769) (2,397) (1,987) (1,719) (1,755) (2,128)
Total non-forecasted trended EE 75 73 69 72 84 95 102 95 77 66 67 73
Net Load Forecast (70 % w/ EE) (1,944) (1,845) (1,691) (1,653) (1,839) (2,199) (2,667) (2,302) (1,910) (1,652) (1,688) (2,055)
Existing Resources
Total Coal 753 732 – – 283 756 797 753 726 294 385 753
Total Gas 503 145 87 – 87 501 503 512 135 – 90 494
Hydro (70th%)—HCC 559 703 586 726 899 605 521 364 419 409 344 459
Hydro (70th%)—Other 208 266 203 256 316 326 277 207 218 217 183 190
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 767 969 789 982 1,215 931 798 571 637 626 527 649
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 377 156 0 0 64 12 0 335 343 0
Existing Resource Subtotal 2,356 2,251 1,691 1,653 2,109 2,730 2,667 2,302 1,942 1,652 1,688 2,225
Monthly Surplus/Deficit 413 406 0 0 270 531 0 0 32 0 (0) 170
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 413 406 0 0 270 531 0 0 32 0 (0) 170

Load and Resource Balance Data Idaho Power Company
Page 38 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024
Forecast EE 75 73 69 72 84 95 102 95 77 66 67 73
Load Forecast (70th% w/EE) (2,046) (1,925) (1,783) (1,747) (1,947) (2,322) (2,803) (2,427) (2,013) (1,741) (1,778) (2,159)
Total non-forecasted trended EE 86 83 79 82 96 109 117 109 88 76 77 83
Net Load Forecast (70 % w/ EE) (1,960) (1,842) (1,703) (1,665) (1,851) (2,213) (2,687) (2,318) (1,925) (1,665) (1,702) (2,075)
Existing Resources
Total Coal 753 732 – – 283 756 797 753 726 294 402 753
Total Gas 503 145 87 – 87 510 503 503 135 – 90 503
Hydro (70th%)—HCC 556 696 585 724 897 602 519 362 412 409 343 450
Hydro (70th%)—Other 208 254 204 252 316 325 276 206 217 216 183 189
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 764 950 789 976 1,213 927 795 568 628 625 526 639
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 343 281 259
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 389 173 0 0 86 41 0 348 341 0
Existing Resource Subtotal 2,353 2,232 1,703 1,665 2,107 2,735 2,687 2,318 1,934 1,665 1,702 2,224
Monthly Surplus/Deficit 392 389 0 0 256 522 0 0 9 0 (0) 149
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 392 389 0 0 256 522 0 0 9 0 (0) 149

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 39
Monthly Average Energy Load and Resource Balance (continued)
1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025
Forecast EE 80 78 74 77 88 99 107 100 81 71 72 78
Load Forecast (70th% w/EE) (2,071) (1,964) (1,803) (1,767) (1,969) (2,349) (2,837) (2,457) (2,037) (1,761) (1,799) (2,186)
Total non-forecasted trended EE 97 94 89 92 106 119 128 120 98 85 87 94
Net Load Forecast (70 % w/ EE) (1,974) (1,870) (1,714) (1,675) (1,864) (2,230) (2,709) (2,337) (1,940) (1,676) (1,713) (2,092)
Existing Resources
Total Coal 753 732 – – 283 756 797 753 726 294 419 753
Total Gas 494 145 87 – 87 510 512 503 135 – 90 503
Hydro (70th%)—HCC 554.8 693.9 583.8 722.3 895.1 598.3 518.1 361.0 407.5 401.0 344.3 446.8
Hydro (70th%)—Other 206.5 242.5 202.4 250.8 315.1 324.5 275.2 204.8 214.9 214.9 181.7 187.3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 761 936 786 973 1,210 923 793 566 622 616 526 634
CSPP (PURPA) 263 339 372 455 472 486 454 400 393 341 278 257
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 402 187 0 0 101 62 12 371 338 0
Existing Resource Subtotal 2,342 2,219 1,714 1,675 2,104 2,730 2,709 2,337 1,940 1,676 1,713 2,217
Monthly Surplus/Deficit 367 349 0 0 241 500 0 0 0 0 (0) 124
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 567 549 200 500 741 1,000 500 500 500 200 200 324

Load and Resource Balance Data Idaho Power Company
Page 40 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026
Forecast EE 86 83 79 81 92 103 111 104 85 75 77 83
Load Forecast (70th% w/EE) (2,095) (1,985) (1,823) (1,787) (1,991) (2,376) (2,871) (2,486) (2,062) (1,781) (1,820) (2,213)
Total non-forecasted trended EE 108 105 100 102 116 130 140 131 108 94 97 105
Net Load Forecast (70 % w/ EE) (1,988) (1,880) (1,724) (1,685) (1,876) (2,246) (2,731) (2,355) (1,954) (1,687) (1,723) (2,108)
Existing Resources
Total Coal 651 651 – – 210 651 651 651 651 294 304 651
Total Gas 494 145 87 – 87 510 494 512 135 – 90 512
Hydro (70th%)—HCC 553 689 583 720 893 597 517 359 403 401 344 446
Hydro (70th%)—Other 206 223 200 246 314 323 274 204 214 214 181 187
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 759 912 783 966 1,207 919 791 563 617 615 525 633
CSPP (PURPA) 260 336 365 448 467 484 452 398 390 338 274 254
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 422 210 0 0 257 177 111 386 336 0
Existing Resource Subtotal 2,234 2,110 1,724 1,685 2,024 2,618 2,697 2,355 1,954 1,687 1,591 2,119
Monthly Surplus/Deficit 246 230 0 0 148 372 (34) 0 0 0 (132) 11
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 446 430 200 500 648 872 466 500 500 200 68 211

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 41
Monthly Average Energy Load and Resource Balance (continued)
1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027
Forecast EE 91 88 84 85 95 107 116 108 89 79 81 88
Load Forecast (70th% w/EE) (2,120) (2,006) (1,843) (1,806) (2,013) (2,403) (2,904) (2,515) (2,086) (1,801) (1,840) (2,241)
Total non-forecasted trended EE 119 116 110 112 126 141 153 143 118 104 107 116
Net Load Forecast (70 % w/ EE) (2,001) (1,890) (1,733) (1,694) (1,887) (2,262) (2,751) (2,372) (1,968) (1,698) (1,733) (2,124)
Existing Resources
Total Coal 651 651 – – 210 651 651 651 651 294 304 651
Total Gas 503 145 87 – 87 510 494 512 135 – 90 494
Hydro (70th%)—HCC 551 679 582 719 892 595 515 358 398 401 344 445
Hydro (70th%)—Other 205 211 199 243 313 322 274 203 211 213 180 185
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 756 891 780 962 1,205 917 789 561 610 614 524 630
CSPP (PURPA) 257 333 365 448 467 484 452 398 390 338 274 254
PPAs
Elkhorn Valley Wind 36 33 36 33 30 32 34 33 27 30 33 35
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 71 67 67 60 52 54 52 54 51 55 63 70
Market Purchases 0 0 434 224 0 0 254 197 132 397 334 26
Existing Resource Subtotal 2,237 2,086 1,733 1,694 2,021 2,616 2,692 2,372 1,968 1,698 1,588 2,124
Monthly Surplus/Deficit 236 196 0 0 134 354 (59) 0 0 0 (146) 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 436 396 200 500 634 854 441 500 500 200 54 200

Load and Resource Balance Data Idaho Power Company
Page 42 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028
Forecast EE 92 88 89 99 111 120 112 93 82 85 92 92
Load Forecast (70th% w/EE) (2,010) (1,864) (1,826) (2,035) (2,429) (2,937) (2,544) (2,111) (1,822) (1,861) (2,268) (2,010)
Total non-forecasted trended EE 128 122 123 137 153 166 156 129 114 118 128 128
Net Load Forecast (70 % w/ EE) (1,881) (1,742) (1,703) (1,898) (2,276) (2,771) (2,388) (1,982) (1,707) (1,743) (2,140) (1,881)
Existing Resources
Total Coal 651 – – 210 651 651 651 651 294 304 651 651
Total Gas 145 87 – 87 501 503 512 135 – 90 494 145
Hydro (70th%)—HCC 675 581 717 890 593 514 357 393 402 344 442 675
Hydro (70th%)—Other 210 194 244 313 321 273 201 210 212 178 184 210
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 885 775 961 1,203 915 787 558 603 614 523 626 885
CSPP (PURPA) 333 365 448 467 484 452 398 390 338 274 254 333
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 8 7 7 8 8 8 10 9 9 9
Neal Hot Springs Geothermal 24 22 19 14 15 11 13 16 15 20 26 24
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 33 31 27 22 22 18 21 24 25 30 35 33
Market Purchases 0 441 267 0 0 249 249 179 405 331 80 0
Existing Resource Subtotal 2,046 1,699 1,703 1,989 2,573 2,659 2,388 1,982 1,676 1,551 2,140 2,046
Monthly Surplus/Deficit 165 (43) 0 91 297 (112) 0 0 (31) (192) 0 165
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 500 500 500 500 500 500 200 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 500 500 500 500 500 500 200 200 200 200
Monthly Surplus/Deficit 365 157 500 591 797 388 500 500 169 8 200 365

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 43
Monthly Average Energy Load and Resource Balance (continued)
1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029
Forecast EE 99 97 92 92 102 114 123 116 96 86 89 97
Load Forecast (70th% w/EE) (2,170) (2,050) (1,885) (1,847) (2,058) (2,457) (2,972) (2,575) (2,136) (1,843) (1,883) (2,294)
Total non-forecasted trended EE 144 140 133 134 148 165 179 168 140 124 129 140
Net Load Forecast (70 % w/ EE) (2,026) (1,910) (1,752) (1,713) (1,911) (2,292) (2,793) (2,407) (1,996) (1,718) (1,753) (2,154)
Existing Resources
Total Coal 651 651 – – 210 651 651 651 651 294 323 651
Total Gas 503 145 87 – 87 501 503 503 135 – 90 503
Hydro (70th%)—HCC 547 672 580 715 888 591 513 355 384 401 344 441
Hydro (70th%)—Other 204 208 193 240 312 320 272 200 209 211 178 182
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 751 880 773 955 1,201 911 785 556 593 612 522 623
CSPP (PURPA) 247 322 352 431 452 469 442 391 380 327 261 241
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 440 300 0 0 245 286 214 403 329 102
Existing Resource Subtotal 2,186 2,031 1,683 1,713 1,972 2,555 2,643 2,407 1,996 1,661 1,553 2,154
Monthly Surplus/Deficit 159 121 (68) 0 61 263 (149) 0 0 (57) (200) 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 359 321 132 500 561 763 351 500 500 143 0 200

Load and Resource Balance Data Idaho Power Company
Page 44 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030
Forecast EE 104 102 97 97 106 118 129 121 101 90 94 102
Load Forecast (70th% w/EE) (2,194) (2,070) (1,904) (1,866) (2,080) (2,483) (3,004) (2,603) (2,160) (1,862) (1,902) (2,320)
Total non-forecasted trended EE 152 147 140 140 154 172 187 175 146 130 136 147
Net Load Forecast (70 % w/ EE) (2,043) (1,922) (1,764) (1,725) (1,926) (2,312) (2,817) (2,428) (2,014) (1,732) (1,767) (2,172)
Existing Resources
Total Coal 651 488 – – 210 651 651 651 651 210 439 651
Total Gas 503 145 87 – 87 510 503 503 90 – – 503
Hydro (70th%)—HCC 546 670 579 713 887 590 511 355 379 401 345 438
Hydro (70th%)—Other 202 207 194 233 312 318 271 200 208 210 177 181
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 748 877 773 946 1,198 908 783 555 587 612 521 620
CSPP (PURPA) 244 319 349 431 452 459 435 386 373 320 251 233
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 60 438 321 0 0 242 305 289 402 327 131
Existing Resource Subtotal 2,180 1,922 1,677 1,725 1,969 2,551 2,631 2,421 2,014 1,569 1,567 2,172
Monthly Surplus/Deficit 137 0 (87) 0 43 240 (186) (7) 0 (163) (200) 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 337 200 113 500 543 740 314 493 500 37 0 200

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 45
Monthly Average Energy Load and Resource Balance (continued)
1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031
Forecast EE 110 107 101 101 110 123 134 126 105 94 98 107
Load Forecast (70th% w/EE) (2,216) (2,088) (1,922) (1,883) (2,099) (2,507) (3,033) (2,629) (2,182) (1,880) (1,920) (2,344)
Total non-forecasted trended EE 159 154 147 146 160 178 194 182 152 136 142 154
Net Load Forecast (70 % w/ EE) (2,057) (1,934) (1,775) (1,737) (1,940) (2,329) (2,839) (2,447) (2,030) (1,744) (1,778) (2,189)
Existing Resources
Total Coal 651 488 – – 210 651 651 651 651 210 247 651
Total Gas 494 145 87 – 87 510 512 503 90 – – 503
Hydro (70th%)—HCC 544 669 578 711 885 588 510 355 374 401 344 435
Hydro (70th%)—Other 202 205 193 226 311 317 271 199 206 209 176 181
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 746 874 770 937 1,196 905 781 553 580 610 521 616
CSPP (PURPA) 213 249 279 352 378 395 388 351 329 269 188 171
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 145 436 420 47 0 238 303 302 400 324 214
Existing Resource Subtotal 2,137 1,934 1,603 1,737 1,940 2,484 2,588 2,382 1,976 1,515 1,309 2,189
Monthly Surplus/Deficit 80 0 (172) 0 0 155 (251) (65) (54) (229) (470) 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 270 270 270 270 270 270 270 270 270 270 270 270
New Resource Subtotal 470 470 470 770 770 770 770 770 770 470 470 470
Monthly Surplus/Deficit 550 470 298 770 770 925 519 705 716 241 0 470

Load and Resource Balance Data Idaho Power Company
Page 46 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032
Forecast EE 114 111 106 105 114 128 140 131 109 98 103 111
Load Forecast (70th% w/EE) (2,236) (2,087) (1,939) (1,900) (2,118) (2,530) (3,062) (2,654) (2,203) (1,897) (1,938) (2,367)
Total non-forecasted trended EE 166 161 153 152 166 185 202 189 158 142 148 161
Net Load Forecast (70 % w/ EE) (2,071) (1,926) (1,786) (1,747) (1,953) (2,346) (2,860) (2,465) (2,045) (1,756) (1,790) (2,206)
Existing Resources
Total Coal 651 488 – – 210 651 651 651 651 210 261 651
Total Gas 494 145 87 – 87 510 494 512 90 – – 494
Hydro (70th%)—HCC 543 667 576 709 883 586 509 353 369 401 344 434
Hydro (70th%)—Other 201 204 191 222 310 316 270 198 205 208 175 179
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 743 871 767 931 1,193 902 779 551 574 610 520 613
CSPP (PURPA) 171 232 265 336 371 388 382 346 323 263 187 170
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 156 434 435 70 0 234 299 302 399 322 243
Existing Resource Subtotal 2,094 1,926 1,583 1,729 1,953 2,474 2,558 2,380 1,964 1,507 1,319 2,206
Monthly Surplus/Deficit 23 0 (202) (18) 0 128 (303) (85) (82) (248) (470) 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 270 270 270 270 270 270 270 270 270 270 270 270
New Resource Subtotal 470 470 470 770 770 770 770 770 770 470 470 470
Monthly Surplus/Deficit 493 470 268 752 770 898 467 685 688 222 (0) 470

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 47
Monthly Average Energy Load and Resource Balance (continued)
1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033
Forecast EE 119 116 110 109 118 132 145 136 113 102 107 116
Load Forecast (70th% w/EE) (2,259) (2,124) (1,957) (1,918) (2,139) (2,556) (3,093) (2,682) (2,227) (1,916) (1,957) (2,392)
Total non-forecasted trended EE 173 168 159 158 171 191 209 196 164 147 154 168
Net Load Forecast (70 % w/ EE) (2,086) (1,956) (1,798) (1,759) (1,968) (2,364) (2,884) (2,485) (2,062) (1,769) (1,802) (2,224)
Existing Resources
Total Coal 651 488 – – 210 651 651 651 651 210 313 651
Total Gas 503 145 87 – 87 510 494 512 90 – – 494
Hydro (70th%)—HCC 542 665 571 707 882 584 507 352 364 401 345 432
Hydro (70th%)—Other 199 203 189 220 309 314 269 197 204 208 174 178
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70 %) 741 868 760 927 1,191 899 777 549 568 608 520 610
CSPP (PURPA) 130 175 208 268 319 335 343 319 280 220 151 134
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 28 247 433 433 139 0 230 296 302 396 319 285
Existing Resource Subtotal 2,086 1,956 1,519 1,656 1,968 2,418 2,512 2,347 1,915 1,460 1,332 2,209
Monthly Surplus/Deficit 0 0 (279) (104) 0 54 (371) (138) (148) (309) (470) (16)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 270 270 270 270 270 270 270 270 270 270 270 270
New Resource Subtotal 470 470 470 770 770 770 770 770 770 470 470 470
Monthly Surplus/Deficit 470 470 191 666 770 824 399 632 622 161 (0) 454

Load and Resource Balance Data Idaho Power Company
Page 48 2015 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034
Forecast EE 124 120 114 113 122 136 149 140 117 105 111 120
Load Forecast (70th% w/EE) (2,280) (2,142) (1,974) (1,935) (2,159) (2,579) (3,123) (2,708) (2,249) (1,934) (1,974) (2,416)
Total non-forecasted trended EE 179 174 166 164 177 198 217 203 170 153 161 174
Net Load Forecast (70 % w/ EE) (2,101) (1,968) (1,808) (1,771) (1,981) (2,382) (2,906) (2,505) (2,079) (1,781) (1,814) (2,242)
Existing Resources
Total Coal 651 488 – – 210 651 651 651 651 210 327 651
Total Gas 503 145 87 – 87 510 494 512 90 – – 494
Hydro (70th%)—HCC 542 664 569 706 881 582 506 350 359 401 345 432
Hydro (70th%)—Other 197 200 187 218 308 313 269 196 203 207 173 177
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 739 864 756 924 1,189 896 775 546 562 607 518 609
CSPP (PURPA) 130 175 208 268 319 335 343 319 280 220 151 134
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange—Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange—Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 44 262 433 433 154 0 230 296 302 396 319 285
Existing Resource Subtotal 2,101 1,968 1,515 1,653 1,981 2,415 2,510 2,345 1,909 1,459 1,344 2,207
Monthly Surplus/Deficit 0 0 (293) (118) 0 33 (396) (160) (170) (322) (470) (35)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 270 270 270 270 270 270 270 270 270 270 270 270
New Resource Subtotal 470 470 470 770 770 770 770 770 770 470 470 470
Monthly Surplus/Deficit 470 470 177 652 770 803 374 610 600 148 0 435

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 49
Monthly Average Energy Surplus/Deficit Charts
Average energy monthly surpluses and deficits with existing DSM and existing resources

Average energy monthly surpluses and deficits with existing DSM, existing resources, IRP DSM, and IRP Resources

Load and Resource Balance Data Idaho Power Company
Page 50 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance
1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015
Load Forecast (95 % w/no DSM) (2,343) (2,412) (2,137) (2,039) (2,697) (3,181) (3,597) (3,044) (2,918) (2,141) (2,245) (2,637)
Existing DSM (EE) 12 12 10 12 15 18 21 15 17 8 12 12
Load Forecast (95 % w/DSM and EE) (2,330) (2,400) (2,128) (2,027) (2,682) (3,163) (3,576) (3,029) (2,901) (2,133) (2,233) (2,625)
Non-forecasted trended EE 0 0 0 0 0 0 0 0 0 0 0 0
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,330) (2,400) (2,128) (2,027) (2,682) (2,773) (3,186) (2,692) (2,901) (2,133) (2,233) (2,625)
Existing Resources
Total Coal 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021
Total Gas 716 716 716 716 716 716 716 716 716 716 716 716
Hydro (90th%)—HCC 1,087 1,078 1,003 1,072 1,119 995 1,000 724 789 878 709 802
Hydro (90th%)—Other 207 209 187 204 303 313 281 208 215 214 200 207
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,294 1,287 1,190 1,276 1,422 1,307 1,281 932 1,004 1,092 909 1,009
CSPP (PURPA) 72 74 77 109 150 157 156 147 135 107 79 75
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 5 6 7 9 10 11 10 7 4 1 3 4
Clatskanie Exchange– Return 0 0 (20) (20) 0 0 0 0 0 (20) (20) 0
Total PPAs 44 44 23 21 37 38 33 33 33 11 18 44
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 3,147 3,141 3,027 3,143 3,345 3,240 3,207 2,849 2,909 2,947 2,743 2,865
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 817 742 899 1,116 663 467 21 157 8 814 510 239

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 51
Peak-Hour Load and Resource Balance (continued)
1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016
Load Forecast (95 % w/no DSM) (2,419) (2,458) (2,201) (2,102) (2,771) (3,294) (3,695) (3,147) (3,018) (2,202) (2,295) (2,681)
Existing DSM (EE) 19 21 20 20 24 28 26 25 25 20 14 18
Load Forecast (95 % w/DSM and EE) (2,400) (2,437) (2,181) (2,082) (2,748) (3,266) (3,669) (3,122) (2,992) (2,183) (2,281) (2,663)
Non-forecasted trended EE 7 8 8 8 9 11 10 10 10 8 5 7
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,393) (2,429) (2,173) (2,075) (2,738) (2,865) (3,270) (2,775) (2,982) (2,175) (2,276) (2,656)
Existing Resources
Total Coal 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021
Total Gas 716 716 716 716 716 716 716 716 716 716 716 716
Hydro (90th%)—HCC 1,086 1,094 1,003 1,073 1,133 993 1,000 722 785 880 710 801
Hydro (90th%)—Other 207 210 187 204 303 312 281 208 215 215 200 207
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,292 1,304 1,189 1,277 1,437 1,305 1,281 930 1,000 1,095 910 1,008
CSPP (PURPA) 72 74 88 120 170 221 220 211 192 139 111 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 0 0 0 0 8 0 25 0 0 0
Existing Resource Subtotal 3,140 3,153 3,051 3,167 3,370 3,291 3,270 2,904 2,982 3,000 2,792 2,861
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 748 724 877 1,092 632 426 0 129 0 825 516 206

Load and Resource Balance Data Idaho Power Company
Page 52 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017
Load Forecast (95 % w/no DSM) (2,453) (2,498) (2,227) (2,130) (2,819) (3,356) (3,773) (3,205) (3,072) (2,236) (2,329) (2,714)
Existing DSM (EE) 27 26 23 27 31 36 36 33 30 27 24 28
Load Forecast (95 % w/DSM and EE) (2,426) (2,472) (2,204) (2,103) (2,788) (3,320) (3,736) (3,172) (3,042) (2,209) (2,305) (2,686)
Non-forecasted trended EE 21 20 18 21 25 28 28 26 23 21 19 22
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,405) (2,452) (2,185) (2,083) (2,763) (2,902) (3,318) (2,809) (3,018) (2,189) (2,286) (2,665)
Existing Resources
Total Coal 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021
Total Gas 716 716 716 716 716 716 716 716 716 716 716 716
Hydro (90th%)—HCC 1,083 1,098 995 1,089 1,143 994 1,000 722 780 880 712 794
Hydro (90th%)—Other 204 209 186 205 305 313 282 208 216 215 196 202
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,286 1,307 1,181 1,295 1,448 1,306 1,282 930 996 1,095 907 997
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 3,137 3,159 3,156 3,299 3,587 3,477 3,447 3,089 3,121 3,094 2,883 2,850
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 732 706 971 1,216 823 575 129 280 102 906 597 186

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 53
Peak-Hour Load and Resource Balance (continued)
1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018
Load Forecast (95 % w/no DSM) (2,468) (2,518) (2,246) (2,143) (2,861) (3,403) (3,847) (3,255) (3,118) (2,263) (2,347) (2,739)
Existing DSM (EE) 35 35 33 34 42 47 54 50 41 35 34 36
Load Forecast (95 % w/DSM and EE) (2,433) (2,483) (2,213) (2,109) (2,820) (3,356) (3,793) (3,205) (3,076) (2,228) (2,313) (2,703)
Non-forecasted trended EE 32 32 31 31 38 44 50 46 38 32 31 33
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,401) (2,451) (2,182) (2,078) (2,781) (2,922) (3,353) (2,822) (3,038) (2,196) (2,282) (2,670)
Existing Resources
Total Coal 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021
Total Gas 716 716 716 716 716 716 716 716 716 716 716 716
Hydro (90th%)—HCC 1,077 1,108 991 1,090 1,147 992 1,000 720 774 878 711 791
Hydro (90th%)—Other 204 208 186 205 305 313 281 208 216 216 195 200
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,281 1,316 1,177 1,295 1,453 1,305 1,281 928 990 1,094 906 991
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 3,131 3,168 3,153 3,300 3,591 3,476 3,446 3,087 3,114 3,094 2,882 2,845
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 731 716 971 1,221 810 554 93 265 77 898 600 175

Load and Resource Balance Data Idaho Power Company
Page 54 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019
Load Forecast (95 % w/no DSM) (2,494) (2,533) (2,272) (2,160) (2,900) (3,447) (3,907) (3,287) (3,162) (2,284) (2,372) (2,763)
Existing DSM (EE) 38 33 42 34 51 60 61 53 55 38 41 40
Load Forecast (95 % w/DSM and EE) (2,456) (2,500) (2,231) (2,127) (2,849) (3,387) (3,847) (3,234) (3,108) (2,246) (2,332) (2,723)
Non-forecasted trended EE 41 36 45 36 54 65 65 57 59 41 44 43
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,415) (2,464) (2,186) (2,090) (2,795) (2,932) (3,391) (2,841) (3,049) (2,205) (2,288) (2,681)
Existing Resources
Total Coal 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021 1,021
Total Gas 716 716 716 716 716 716 716 716 716 716 716 716
Hydro (90th%)—HCC 1,077 1,123 977 1,088 1,155 996 1,000 720 769 880 712 772
Hydro (90th%)—Other 203 208 195 204 306 314 281 208 216 217 189 190
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,280 1,331 1,172 1,293 1,462 1,309 1,281 928 985 1,098 902 961
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 0 0 0 0 0 0 0 0 0 0
Existing Resource Subtotal 3,131 3,183 3,147 3,297 3,600 3,480 3,446 3,087 3,109 3,097 2,878 2,815
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 716 718 962 1,207 805 548 55 246 60 892 590 134

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 55
Peak-Hour Load and Resource Balance (continued)
1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020
Load Forecast (95 % w/no DSM) (2,521) (2,563) (2,289) (2,195) (2,945) (3,504) (3,991) (3,331) (3,218) (2,298) (2,401) (2,796)
Existing DSM (EE) 42 47 40 50 63 78 86 61 75 34 50 50
Load Forecast (95 % w/DSM and EE) (2,479) (2,515) (2,249) (2,145) (2,882) (3,426) (3,905) (3,270) (3,143) (2,264) (2,351) (2,747)
Non-forecasted trended EE 40 46 38 48 61 76 83 59 73 33 48 48
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,439) (2,470) (2,210) (2,097) (2,821) (2,961) (3,432) (2,874) (3,071) (2,231) (2,303) (2,699)
Existing Resources
Total Coal 1,021 1,021 55 55 1,021 1,021 1,021 1,021 1,021 758 758 1,021
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,073 1,098 977 1,084 1,152 992 1,000 716 760 880 710 771
Hydro (90th%)—Other 203 207 194 204 305 312 281 207 214 216 189 190
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,276 1,305 1,171 1,288 1,457 1,304 1,281 924 974 1,097 899 961
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 29 70 0 0 0 0 0 0 0 0
Existing Resource Subtotal 3,127 3,157 2,210 2,097 3,596 3,475 3,446 3,082 3,098 2,533 2,612 2,815
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 688 687 0 0 774 514 13 208 28 302 309 116

Load and Resource Balance Data Idaho Power Company
Page 56 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021
Load Forecast (95 % w/no DSM) (2,551) (2,594) (2,316) (2,213) (2,983) (3,549) (4,051) (3,386) (3,260) (2,330) (2,417) (2,824)
Existing DSM (EE) 57 63 53 55 67 79 85 76 78 46 52 57
Load Forecast (95 % w/DSM and EE) (2,495) (2,531) (2,263) (2,158) (2,916) (3,469) (3,965) (3,310) (3,182) (2,284) (2,365) (2,766)
Non-forecasted trended EE 56 62 52 54 66 78 84 75 77 46 51 56
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,439) (2,469) (2,211) (2,104) (2,850) (3,001) (3,491) (2,897) (3,105) (2,238) (2,314) (2,710)
Existing Resources
Total Coal 966 966 0 0 966 966 966 966 966 703 703 966
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,070 1,072 968 1,083 1,149 988 1,000 713 748 879 710 770
Hydro (90th%)—Other 201 205 194 203 304 311 280 206 213 215 188 189
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,271 1,277 1,162 1,286 1,454 1,300 1,280 919 961 1,094 898 959
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 94 135 0 0 102 0 75 0 0 0
Existing Resource Subtotal 3,067 3,074 2,211 2,104 3,537 3,415 3,491 3,023 3,105 2,476 2,556 2,757
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 628 605 0 0 687 414 0 125 0 237 242 47

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 57
Peak-Hour Load and Resource Balance (continued)
1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022
Load Forecast (95 % w/no DSM) (2,620) (2,348) (2,236) (3,029) (3,610) (4,117) (3,431) (3,308) (2,371) (2,431) (2,852) (2,620)
Existing DSM (EE) 70 67 64 77 100 91 83 87 64 48 60 70
Load Forecast (95 % w/DSM and EE) (2,550) (2,281) (2,173) (2,952) (3,510) (4,026) (3,348) (3,221) (2,307) (2,383) (2,792) (2,550)
Non-forecasted trended EE 73 70 66 81 103 94 86 91 67 50 62 73
Existing Demand Response 0 0 0 0 390 390 337 0 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,477) (2,211) (2,107) (2,871) (3,017) (3,541) (2,925) (3,130) (2,240) (2,333) (2,729) (2,477)
Existing Resources
Total Coal 966 0 0 966 966 966 966 966 703 703 966 966
Total Gas 716 716 416 716 716 716 716 716 416 716 716 716
Hydro (90th%)—HCC 1,061 964 1,081 1,147 986 1,000 709 736 879 711 768 1,061
Hydro (90th%)—Other 204 192 203 304 310 279 205 211 214 187 188 204
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,265 1,156 1,283 1,450 1,296 1,279 914 947 1,093 898 956 1,265
CSPP (PURPA) 76 203 235 375 406 405 396 359 232 204 77 76
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 8 7 7 8 8 8 10 9 9 9
Neal Hot Springs Geothermal 24 22 19 14 15 11 13 16 15 20 26 24
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 38 36 32 27 27 23 26 29 30 35 40 38
Market Purchases 0 100 140 0 0 152 0 113 0 0 0 0
Existing Resource Subtotal 3,062 2,211 2,107 3,534 3,412 3,541 3,018 3,130 2,474 2,556 2,755 3,062
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 585 0 0 663 395 0 93 0 234 222 25 585

Load and Resource Balance Data Idaho Power Company
Page 58 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023
Load Forecast (95 % w/no DSM) (2,617) (2,647) (2,374) (2,271) (3,080) (3,664) (4,201) (3,485) (3,346) (2,405) (2,477) (2,903)
Existing DSM (EE) 76 74 71 77 92 112 114 99 85 75 70 82
Load Forecast (95 % w/DSM and EE) (2,541) (2,572) (2,303) (2,194) (2,987) (3,552) (4,086) (3,387) (3,261) (2,330) (2,406) (2,822)
Non-forecasted trended EE 83 82 78 85 101 123 125 108 93 82 77 90
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,457) (2,491) (2,225) (2,109) (2,886) (3,039) (3,571) (2,941) (3,167) (2,248) (2,329) (2,732)
Existing Resources
Total Coal 966 966 0 0 966 966 966 966 966 703 703 966
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,063 1,058 961 1,079 1,144 984 1,000 706 724 877 712 766
Hydro (90th%)—Other 199 202 191 202 303 309 278 204 210 211 186 187
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,262 1,260 1,152 1,281 1,447 1,293 1,278 910 934 1,088 898 952
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 119 144 0 0 183 0 163 0 0 0
Existing Resource Subtotal 3,058 3,057 2,225 2,109 3,531 3,408 3,571 3,014 3,167 2,469 2,556 2,751
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 601 566 0 0 645 369 0 72 0 221 226 19

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 59
Peak-Hour Load and Resource Balance (continued)
1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024
Load Forecast (95 % w/no DSM) (2,658) (2,679) (2,413) (2,283) (3,120) (3,721) (4,268) (3,534) (3,412) (2,428) (2,514) (2,931)
Existing DSM (EE) 85 83 85 65 95 121 117 103 107 74 81 79
Load Forecast (95 % w/DSM and EE) (2,573) (2,596) (2,328) (2,218) (3,025) (3,600) (4,151) (3,431) (3,305) (2,354) (2,433) (2,853)
Non-forecasted trended EE 98 95 97 75 109 139 134 118 122 85 93 90
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,475) (2,500) (2,231) (2,143) (2,917) (3,071) (3,626) (2,976) (3,183) (2,269) (2,340) (2,762)
Existing Resources
Total Coal 966 966 0 0 966 966 966 966 966 703 703 966
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,060 1,054 958 1,077 1,141 982 1,000 703 716 877 711 767
Hydro (90th%)—Other 198 202 191 202 302 308 277 203 208 209 185 186
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,258 1,256 1,149 1,279 1,443 1,290 1,277 905 924 1,086 896 953
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 127 181 0 0 239 0 189 0 0 11
Existing Resource Subtotal 3,054 3,053 2,231 2,143 3,527 3,405 3,626 3,009 3,183 2,467 2,554 2,762
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 0 0 0 0 0 0 0 0 0 0 0 0
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 0 0 0 0 0 0 0 0 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 579 552 0 0 610 335 0 33 0 198 214 0

Load and Resource Balance Data Idaho Power Company
Page 60 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025
Load Forecast (95 % w/no DSM) (2,673) (2,698) (2,438) (2,308) (3,164) (3,773) (4,350) (3,571) (3,454) (2,453) (2,533) (2,970)
Existing DSM (EE) 72 81 89 67 101 124 136 94 105 76 76 90
Load Forecast (95 % w/DSM and EE) (2,601) (2,617) (2,350) (2,240) (3,062) (3,648) (4,215) (3,476) (3,349) (2,377) (2,456) (2,880)
Non-forecasted trended EE 86 97 106 81 121 149 163 113 126 92 92 108
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,515) (2,520) (2,243) (2,159) (2,941) (3,109) (3,661) (3,026) (3,224) (2,285) (2,365) (2,772)
Existing Resources
Total Coal 966 966 0 0 966 966 966 966 966 703 703 966
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,052 1,050 956 1,075 1,133 981 1,000 699 708 874 713 765
Hydro (90th%)—Other 197 202 190 201 296 302 277 202 207 209 184 185
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,250 1,252 1,146 1,276 1,430 1,283 1,277 901 914 1,082 897 950
CSPP (PURPA) 74 76 203 235 375 406 405 396 359 232 204 76
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 142 200 0 0 261 21 240 0 0 24
Existing Resource Subtotal 3,045 3,048 2,243 2,159 3,513 3,398 3,648 3,026 3,224 2,463 2,555 2,772
Monthly Surplus/Deficit 0 0 0 0 0 0 (14) 0 0 0 0 0
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 731 728 200 500 1,072 789 486 500 500 378 390 200

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 61
Peak-Hour Load and Resource Balance (continued)
1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026
Load Forecast (95 % w/no DSM) (2,723) (2,734) (2,444) (2,348) (3,203) (3,830) (4,425) (3,623) (3,522) (2,461) (2,571) (2,995)
Existing DSM (EE) 96 97 73 87 103 133 147 103 129 61 93 89
Load Forecast (95 % w/DSM and EE) (2,627) (2,637) (2,370) (2,261) (3,099) (3,697) (4,278) (3,521) (3,393) (2,399) (2,479) (2,906)
Non-forecasted trended EE 121 122 92 109 130 168 185 129 162 77 117 112
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,506) (2,515) (2,278) (2,152) (2,969) (3,139) (3,703) (3,054) (3,231) (2,322) (2,362) (2,794)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,047 1,047 954 1,073 1,131 979 1,000 696 697 874 713 762
Hydro (90th%)—Other 197 201 190 200 293 299 276 201 205 208 183 184
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,244 1,247 1,143 1,274 1,424 1,278 1,276 897 902 1,082 896 947
CSPP (PURPA) 74 76 202 234 374 405 404 395 358 231 203 76
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 181 196 0 10 257 305 302 0 0 301
Existing Resource Subtotal 2,776 2,781 2,278 2,152 3,243 3,139 3,379 3,042 3,010 2,462 2,553 2,782
Monthly Surplus/Deficit 0 0 0 0 0 0 (324) (13) (221) 0 0 (12)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 470 466 200 500 774 500 176 487 279 340 391 188

Load and Resource Balance Data Idaho Power Company
Page 62 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027
Load Forecast (95 % w/no DSM) (2,748) (2,762) (2,480) (2,368) (3,239) (3,863) (4,476) (3,681) (3,558) (2,498) (2,588) (3,026)
Existing DSM (EE) 95 106 89 86 103 119 134 117 121 77 88 94
Load Forecast (95 % w/DSM and EE) (2,653) (2,656) (2,391) (2,281) (3,136) (3,744) (4,341) (3,565) (3,437) (2,422) (2,500) (2,932)
Non-forecasted trended EE 125 139 118 114 136 157 177 154 160 101 116 124
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,528) (2,517) (2,273) (2,167) (2,999) (3,197) (3,774) (3,074) (3,277) (2,321) (2,384) (2,809)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,044 1,039 949 1,071 1,128 978 1,000 692 687 874 711 761
Hydro (90th%)—Other 196 198 190 200 292 298 275 200 204 207 183 183
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,240 1,237 1,139 1,271 1,421 1,276 1,275 892 890 1,080 894 944
CSPP (PURPA) 73 75 202 234 374 405 404 395 358 231 203 76
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 39 38 36 32 27 27 23 26 29 30 35 40
Market Purchases 0 0 181 214 0 70 254 305 302 0 0 298
Existing Resource Subtotal 2,771 2,770 2,273 2,167 3,240 3,197 3,375 3,037 2,998 2,461 2,551 2,777
Monthly Surplus/Deficit 0 0 0 0 0 0 (399) (37) (279) 0 0 (32)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 444 453 200 500 741 500 101 463 221 340 367 168

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 63
Peak-Hour Load and Resource Balance (continued)
1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028
Load Forecast (95 % w/no DSM) (2,780) (2,786) (2,507) (2,406) (3,278) (3,930) (4,558) (3,721) (3,597) (2,542) (2,629) (3,059)
Existing DSM (EE) 100 111 95 103 106 138 153 112 116 98 106 100
Load Forecast (95 % w/DSM and EE) (2,680) (2,675) (2,412) (2,303) (3,172) (3,792) (4,404) (3,609) (3,481) (2,444) (2,523) (2,960)
Non-forecasted trended EE 139 154 132 142 148 192 212 155 161 136 147 138
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,541) (2,521) (2,281) (2,161) (3,025) (3,210) (3,802) (3,117) (3,320) (2,308) (2,377) (2,821)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,040 1,041 945 1,070 1,126 976 1,000 689 673 872 713 756
Hydro (90th%)—Other 195 197 189 199 292 297 275 199 202 206 181 182
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,236 1,238 1,134 1,269 1,418 1,274 1,275 888 875 1,078 895 938
CSPP (PURPA) 73 75 202 234 374 405 404 395 358 231 203 76
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 198 214 0 90 249 305 302 0 0 295
Existing Resource Subtotal 2,762 2,766 2,281 2,161 3,233 3,210 3,364 3,028 2,977 2,453 2,547 2,762
Monthly Surplus/Deficit 0 0 0 0 0 0 (438) (88) (343) 0 0 (59)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 421 445 200 500 708 500 62 412 157 345 370 141

Load and Resource Balance Data Idaho Power Company
Page 64 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029
Load Forecast (95 % w/no DSM) (2,823) (2,808) (2,544) (2,426) (3,328) (3,988) (4,631) (3,814) (3,643) (2,572) (2,657) (3,105)
Existing DSM (EE) 115 111 110 102 118 146 162 159 117 104 111 120
Load Forecast (95 % w/DSM and EE) (2,708) (2,697) (2,434) (2,325) (3,210) (3,842) (4,469) (3,655) (3,527) (2,468) (2,546) (2,985)
Non-forecasted trended EE 167 161 160 148 171 212 235 230 169 151 160 174
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,541) (2,535) (2,274) (2,177) (3,039) (3,240) (3,844) (3,088) (3,357) (2,316) (2,386) (2,811)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 716 716
Hydro (90th%)—HCC 1,037 1,037 941 1,068 1,124 975 1,000 686 663 872 712 752
Hydro (90th%)—Other 195 196 189 199 288 292 274 198 200 205 180 180
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,232 1,233 1,130 1,267 1,411 1,267 1,274 884 863 1,077 892 933
CSPP (PURPA) 71 73 200 231 371 402 401 392 355 229 201 73
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 197 235 0 130 245 305 302 0 0 293
Existing Resource Subtotal 2,757 2,759 2,274 2,177 3,223 3,240 3,357 3,021 2,962 2,450 2,542 2,753
Monthly Surplus/Deficit 0 0 0 0 0 0 (487) (66) (395) 0 0 (58)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 0 0 0 0 0 0 0
2030 Ice TES 0 0 0 0 0 0 0 0 0 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 500 500 500 500 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 416 424 200 500 684 500 13 434 105 334 356 142

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 65
Peak-Hour Load and Resource Balance (continued)
1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030
Load Forecast (95 % w/no DSM) (2,838) (2,809) (2,575) (2,432) (3,366) (4,045) (4,677) (3,829) (3,711) (2,589) (2,682) (3,121)
Existing DSM (EE) 106 94 122 88 120 157 146 131 142 99 115 112
Load Forecast (95 % w/DSM and EE) (2,732) (2,715) (2,453) (2,344) (3,246) (3,888) (4,531) (3,698) (3,569) (2,489) (2,567) (3,009)
Non-forecasted trended EE 154 136 177 128 174 228 211 190 206 144 167 162
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,578) (2,579) (2,276) (2,216) (3,071) (3,270) (3,930) (3,171) (3,363) (2,346) (2,400) (2,847)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 416 716
Hydro (90th%)—HCC 1,035 1,034 938 1,066 1,121 973 1,000 682 652 873 712 752
Hydro (90th%)—Other 194 194 188 198 288 292 273 197 199 204 180 180
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,229 1,228 1,126 1,264 1,409 1,265 1,273 879 851 1,077 892 931
CSPP (PURPA) 71 73 200 231 371 401 400 390 353 227 199 72
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 204 277 0 163 242 305 302 0 161 291
Existing Resource Subtotal 2,754 2,753 2,276 2,216 3,221 3,270 3,352 3,015 2,949 2,448 2,400 2,748
Monthly Surplus/Deficit 0 0 0 0 0 0 (579) (156) (414) 0 0 (99)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 60 60 60 0 0 0 0
2030 Ice TES 0 0 0 0 20 20 20 20 20 0 0 0
2031 Combined Cycle Combustion Turbine 0 0 0 0 0 0 0 0 0 0 0 0
New Resource Subtotal 200 200 200 500 520 580 580 580 520 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 375 374 200 500 669 580 1 424 106 302 200 101

Load and Resource Balance Data Idaho Power Company
Page 66 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031
Load Forecast (95 % w/no DSM) (2,852) (2,842) (2,592) (2,448) (3,407) (4,091) (4,764) (3,855) (3,744) (2,614) (2,691) (3,150)
Existing DSM (EE) 101 112 123 89 127 160 172 118 135 104 108 119
Load Forecast (95 % w/DSM and EE) (2,751) (2,730) (2,469) (2,359) (3,280) (3,931) (4,592) (3,737) (3,608) (2,509) (2,584) (3,031)
Non-forecasted trended EE 145 162 178 129 184 232 250 170 196 151 156 172
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,606) (2,569) (2,292) (2,230) (3,095) (3,309) (3,952) (3,230) (3,412) (2,358) (2,428) (2,859)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 416 716
Hydro (90th%)—HCC 1,034 1,029 935 1,064 1,119 972 1,000 679 641 869 714 749
Hydro (90th%)—Other 193 193 187 197 287 291 272 196 197 202 179 178
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,226 1,222 1,122 1,262 1,406 1,262 1,272 876 839 1,071 893 926
CSPP (PURPA) 66 63 190 221 360 391 390 381 344 218 189 61
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 233 304 0 214 238 303 302 0 198 289
Existing Resource Subtotal 2,746 2,737 2,292 2,230 3,207 3,309 3,338 3,000 2,927 2,433 2,428 2,730
Monthly Surplus/Deficit 0 0 0 0 0 0 (615) (230) (485) 0 0 (129)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 60 60 60 0 0 0 0
2030 Ice TES 0 0 0 0 20 20 20 20 20 0 0 0
2031 Combined Cycle Combustion Turbine 300 300 300 300 300 300 300 300 300 300 300 300
New Resource Subtotal 500 500 500 800 820 880 880 880 820 500 500 500
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 640 668 500 800 932 880 265 650 335 575 500 371

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 67
Peak-Hour Load and Resource Balance (continued)
1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032
Load Forecast (95 % w/no DSM) (2,902) (2,877) (2,599) (2,481) (3,438) (4,114) (4,818) (3,916) (3,798) (2,625) (2,715) (3,172)
Existing DSM (EE) 130 132 113 106 125 141 167 140 151 97 114 119
Load Forecast (95 % w/DSM and EE) (2,772) (2,745) (2,486) (2,375) (3,313) (3,972) (4,651) (3,776) (3,647) (2,529) (2,601) (3,054)
Non-forecasted trended EE 188 191 164 153 181 205 241 203 218 140 165 171
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,584) (2,554) (2,322) (2,223) (3,132) (3,377) (4,020) (3,236) (3,429) (2,389) (2,437) (2,882)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 416 716
Hydro (90th%)—HCC 1,032 1,025 932 1,063 1,118 971 1,000 676 630 869 714 746
Hydro (90th%)—Other 192 192 187 196 285 289 272 195 196 201 178 176
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,224 1,218 1,119 1,259 1,403 1,259 1,272 871 826 1,070 892 922
CSPP (PURPA) 59 60 187 219 359 390 389 380 343 216 188 61
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 269 301 0 287 234 299 302 0 208 287
Existing Resource Subtotal 2,736 2,730 2,322 2,223 3,203 3,377 3,331 2,990 2,914 2,431 2,437 2,724
Monthly Surplus/Deficit 0 0 0 0 0 0 (689) (245) (515) 0 0 (158)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 60 60 60 0 0 0 0
2030 Ice TES 0 0 0 0 20 20 20 20 20 0 0 0
2031 Combined Cycle Combustion Turbine 300 300 300 300 300 300 300 300 300 300 300 300
New Resource Subtotal 500 500 500 800 820 880 880 880 820 500 500 500
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 652 677 500 800 890 880 191 635 305 542 500 342

Load and Resource Balance Data Idaho Power Company
Page 68 2015 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033
Load Forecast (95 % w/no DSM) (2,920) (2,903) (2,622) (2,502) (3,478) (4,163) (4,886) (3,962) (3,845) (2,650) (2,739) (3,200)
Existing DSM (EE) 126 141 118 109 129 146 173 145 157 101 119 123
Load Forecast (95 % w/DSM and EE) (2,794) (2,763) (2,504) (2,393) (3,348) (4,017) (4,713) (3,817) (3,688) (2,549) (2,620) (3,077)
Non-forecasted trended EE 183 204 171 158 187 212 251 210 228 146 172 179
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,611) (2,559) (2,332) (2,235) (3,161) (3,415) (4,071) (3,270) (3,461) (2,404) (2,448) (2,899)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 416 716
Hydro (90th%)—HCC 1,030 1,004 929 1,061 1,116 969 1,000 673 620 870 712 745
Hydro (90th%)—Other 191 191 186 196 282 285 271 194 195 200 177 175
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,221 1,195 1,115 1,257 1,398 1,254 1,271 867 814 1,070 889 921
CSPP (PURPA) 50 52 178 210 350 381 380 371 334 208 179 52
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 292 324 0 328 230 296 302 0 231 285
Existing Resource Subtotal 2,724 2,699 2,332 2,235 3,189 3,404 3,318 2,974 2,893 2,422 2,448 2,712
Monthly Surplus/Deficit 0 0 0 0 0 (11) (754) (296) (568) 0 0 (187)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 60 60 60 0 0 0 0
2030 Ice TES 0 0 0 0 20 20 20 20 20 0 0 0
2031 Combined Cycle Combustion Turbine 300 300 300 300 300 300 300 300 300 300 300 300
New Resource Subtotal 500 500 500 800 820 880 880 880 820 500 500 500
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 613 640 500 800 848 869 126 584 252 518 500 313

Idaho Power Company Load and Resource Balance Data
2015 Integrated Resource Plan—Appendix C Page 69
Peak-Hour Load and Resource Balance (continued)
1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034
Load Forecast (95 % w/no DSM) (2,955) (2,917) (2,652) (2,539) (3,531) (4,241) (4,966) (4,017) (3,870) (2,698) (2,768) (3,256)
Existing DSM (EE) 141 139 132 130 149 181 193 160 142 129 131 156
Load Forecast (95 % w/DSM and EE) (2,815) (2,778) (2,520) (2,409) (3,382) (4,060) (4,773) (3,857) (3,728) (2,569) (2,638) (3,100)
Non-forecasted trended EE 204 202 192 189 217 264 280 232 206 188 190 226
Existing Demand Response 0 0 0 0 0 390 390 337 0 0 0 0
Peak-Hour Forecast w/DSM (EE) (2,610) (2,576) (2,328) (2,220) (3,166) (3,406) (4,103) (3,287) (3,522) (2,381) (2,448) (2,873)
Existing Resources
Total Coal 703 703 0 0 703 703 703 703 703 703 703 703
Total Gas 716 716 716 416 716 716 716 716 716 416 416 716
Hydro (90th%)—HCC 1,028 992 926 1,059 1,114 968 1,000 669 612 868 712 743
Hydro (90th%)—Other 190 190 186 195 278 283 270 193 194 200 176 174
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90 %) 1,219 1,181 1,112 1,254 1,392 1,251 1,270 862 806 1,068 888 917
CSPP (PURPA) 50 52 178 210 350 381 380 371 334 208 179 52
PPAs
Elkhorn Valley Wind 0 0 0 0 0 0 0 0 0 0 0 0
Raft River Geothermal 9 9 9 8 7 7 8 8 8 10 9 9
Neal Hot Springs Geothermal 25 24 22 19 14 15 11 13 16 15 20 26
Clatskanie Exchange–Take 0 0 0 0 0 0 0 0 0 0 0 0
Clatskanie Exchange– Return 0 0 0 0 0 0 0 0 0 0 0 0
Total PPAs 34 33 31 27 22 22 18 21 24 25 30 35
Market Purchases 0 0 291 313 0 328 230 296 302 0 232 285
Existing Resource Subtotal 2,721 2,685 2,328 2,220 3,183 3,401 3,317 2,970 2,884 2,420 2,448 2,708
Monthly Surplus/Deficit 0 0 0 0 0 (5) (786) (318) (638) 0 0 (165)
2015 IRP Resources
2025 Boardman to Hemingway Transmission 200 200 200 500 500 500 500 500 500 200 200 200
2030 New DR 0 0 0 0 0 60 60 60 0 0 0 0
2030 Ice TES 0 0 0 0 20 20 20 20 20 0 0 0
2031 Combined Cycle Combustion Turbine 300 300 300 300 300 300 300 300 300 300 300 300
New Resource Subtotal 500 500 500 800 820 880 880 880 820 500 500 500
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 611 609 500 800 837 875 94 562 182 538 500 335

Load and Resource Balance Data Idaho Power Company
Page 70 2015 Integrated Resource Plan—Appendix C
Peak-Hour Surplus/Deficit Charts
Peak-hour monthly deficits with existing DSM and existing resources

Peak-hour monthly deficits with existing DSM, existing resources, IRP DSM, and IRP resources

(1,000)
(800)
(600)
(400)
(200)
0
01
/
2
0
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3
4
MW
Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 71
DEMAND-SIDE RESOURCE DATA
Cost Effectiveness
Idaho Power considers cost-effectiveness to be the primary screening tool prior to demand-side
management (DSM) program implementation. Idaho Power uses the total resource cost (TRC) test and
the utility cost (UC) test to develop benefit cost (B/C) ratios to determine the cost-effectiveness of DSM
programs for inclusion in resource planning. The two tests insure that the program benefits will exceed
costs from both the perspective of Idaho Power (UC) and its customers (TRC). For ongoing programs, tests are also run to look at cost-effectiveness from the point of view of the program participant.
Each energy efficiency and demand response program and individual program measures are reviewed
annually as part of preparation of an annual report that is submitted to both the Idaho and Oregon public
utility commissions. More information on Idaho Power’s programs and cost-effectiveness are included
in the Demand-Side Management 2012 Annual Report and its Supplement 1: Cost-Effectiveness, (idahopower.com/EnergyEfficiency/reports.cfm).
Incorporated into the cost-effectiveness analysis are inputs from various sources that represent the most
current and reliable information available. Measure savings, measure life, and participant cost
assumptions for prescriptive programs are usually sourced from the Regional Technical Forum (RTF),
which is the regional advisory group and technical arm of the Northwest Power and Conservation Council (NPCC). For custom and non-prescriptive programs, annual energy savings can be derived from
program evaluations, engineering estimates, or regionally deemed values. Participant costs for
non-prescriptive programs are often actual costs from customer-submitted information. Other inputs
used in the cost-effectiveness models are obtained from the IRP process, including the financial
assumptions along with the forecasted value of DSM alternative costs.
Idaho Power determines cost-effectiveness on both a program basis and also on a measure-by-measure
basis. In all cases, when cost-effectiveness is calculated for one measure or for an entire program, to be
considered cost-effective, the B/C ratios must be greater than one for both the TRC and UC tests.
For the 2015 IRP, non-energy related benefits (NEB) were included in the cost-effectiveness analysis of
the program forecasts. NEB include savings from the customer’s perspective, including water savings, deferred maintenance and operational costs, health and safety benefits, avoided supplemental fuels,
and other quantifiable benefits apart from avoided energy production. NEB were applied to the energy
efficiency forecast at the sector level based on cost-effectiveness analysis of the 2014 portfolio of
programs. For a complete list of NEB and sources that Idaho Power currently uses for its program
cost-effectiveness, see Demand-Side Management 2014 Annual Report and its Supplement 1: Cost-Effectiveness, (idahopower.com/EnergyEfficiency/reports.cfm).
The cost-effective analysis methods used at Idaho Power are consistent with published methods and
standard practices. Idaho Power relies on the Electric Power Research Institute End Use Technical Assessment Guide (TAG) Understanding Cost-Effectiveness of Energy Efficiency Programs, and the California Standard Practice Manual for the cost-effectiveness methodology. As defined in the TAG
and California Standard Practice Manual, the TRC and UC tests are most similar to supply-side cost
analysis and provide a useful basis to compare demand-side and supply-side resources.
Resource Development and Evaluation
When developing energy efficiency programs, Idaho Power uses actual data and experiences from other
companies in the region, or throughout the country, where applicable, to help identify specific program
Demand-Side Resource Data Idaho Power Company
Page 72 2015 Integrated Resource Plan—Appendix C
parameters. The regional program review is typically accomplished through discussions with other
utilities’ program managers and research staff. Other program development resources include; E Source,
Edison Electrical Institute (EEI), Consortium for Energy Efficiency (CEE), American Council for an
Energy Efficient Economy (ACEEE), Advanced Load Control Alliance (ALCA). For other assumptions, including estimated cost, savings, Idaho Power relies on sources, such as the NPCC, the RTF, NEEA,
the Database for Energy Efficiency Resources (DEER), third-party consultants, and other
regional utilities.
Sometimes Idaho Power launches pilot programs or limited-scale programs; to evaluate estimates or
assumptions in the cost-effectiveness model. Pilot programs are designed to measure actual program experiences, including program expenses, savings, and participation. Following implementation of a
program, the cost-effectiveness models are reviewed as data from actual program activity becomes
available. The program design may be re-examined after program implementation.
All programs are included in an ongoing evaluation schedule where a third-party consultant verifies the
claimed savings from the program. Programs are also evaluated to review the program processes to review the effectiveness of the program delivery. If an evaluation determines that savings are less than
claimed or that there is potential for improvement in delivery of the program then changes can be made
based on the recommendations. Recent evaluations from the 2014 program year can be reviewed in the
Demand-Side Management 2014 Annual Report and its Supplement 2: Evaluations,
(idahopower.com/EnergyEfficiency/reports.cfm).
Planning Assumptions and Alternate Costs
The financial assumptions used in the analysis for the 2015 IRP are consistent with the financial
assumptions made for supply-side resources, including the discount rate and cost escalation rates. Table DSM-1 lists the financial assumptions The IRP is also the source of the DSM alternative costs,
which is the basis for estimating the value of energy savings and demand reduction resulting from the
DSM programs. The DSM alternative costs vary by season and time-of-day. The DSM alternative
energy costs are based on either projected fuel costs of a natural gas peaking unit for peak summer hours
or forward marginal prices as determined by the AURORAxmp® Electric Market Model. The avoided capacity resource for peak summer hours and for demand response programs is based on a 170 MW
natural gas-fired, simple-cycle combustion turbine (SCCT).
The prices of avoided energy throughout the 20-year planning period were simulated using 2015 IRP
Portfolio 6b. Portfolio 6b was run assuming 111d sensitivity #5 within the AURORA model.
The AURORA model is a production cost tool that simulates hourly economic dispatch and commitment of supply-side, demand-side, and transmission resources. Idaho Power’s setup of the AURORA model
forecasts electric market prices throughout the Western Electricity Coordinating Council (WECC)
region. AURORA also forecasts marginal electricity costs for Idaho Power. Marginal electricity costs
are set by the highest variable cost resource that is dispatched in any given forecasted hour.
Variable costs include variable O&M and variable fuel costs. Idaho Power modeled hourly, marginal electricity costs for the years 2015 through 2034 to estimate the potential system benefit of
avoiding production of the next unit of energy. An initial run of marginal costs are run during the
preliminary analysis phase of the IRP process. The preliminary runs will combine updated planning
assumptions including load and natural gas price forecasts run against the current preferred resource
portfolio from the previous IRP. After the selection of the preferred portfolio which for the 2015 IRP is portfolio 6b, a final run of marginal prices are run which become the avoided energy prices for DSM
energy valuation until the next IRP cycle.
Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 73
The forward prices are placed into five homogenous pricing categories for the convenience of
cost-effectiveness calculation the categories follow the pattern of heavy and light load pricing
throughout each year of the planning period. The resulting categories include the following:
• Summer On-Peak (SONP)—Average of Idaho Power variable energy and operating costs of a 170 MW SCCT, which is the marginal resource for peak hour load deficits during summertime
heavy load hours
• Summer Mid-Peak (SMP)—Average of heavy load prices from June to August (excluding the SONP hours)
• Summer Off-Peak (SOFP)—Average of light load prices from June to August
• Non-Summer Mid-Peak (NSMP)—Average of heavy load prices in January through May and
September through December
• Non-Summer Off-Peak (NSOFP)—Average of light load prices in January through May and September through December
The SONP is treated differently than the other four pricing periods when valuing energy efficiency.
The estimated levelized capacity cost of a new SCCT is approximately $119 per kW over a 30-year
period. The avoided capacity value is spread across the annual SONP hours to estimate the value of energy efficiency savings occurring during the hours. The total SONP hours vary between 512 to
528 hours depending on the year. When the levelized capacity cost of a new SCCT ($119/kW) is
multiplied by the Effective Load Carry Capacity (ELCC) of 89 percent which is the estimated percent of
top 100 peak load hours that demand response can cover, the annual avoided capacity cost is $106/kW.
For demand response or direct load control DSM programs $106 per kW becomes the cost threshold for program cost-effectiveness on an annual per kW basis.
Annual benefits for demand response are also established as part of the IRP process once the value of
the 170 MW SCCT is determined. The method for determining cost-effectiveness for demand response
programs was updated in 2014 as part of a series of public workshop supporting IPUC Case No. IP-E-
13-14 resulting in orders from both the IPUPC (No. 32980) and Oregon (No.13-482). The orders established that through the IRP process IPC will establish an annual operating cost ceiling tied to the
levelized annual benefit of a 170-MW SCCT. The updated established annual value for the 2015 IRP is
$18.5 million which is an increase from 16.7 million from the 2013 IRP. While the intent of the benefit
calculation provides guidance for annual cost limit to operating demand response in years with no
anticipated peak deficits, actual 2014 operating costs of demand response programs were considerable less at 10.6 million.
Forecast and Cost-Effectiveness Data
Table DSM-1 lists the financial assumptions used for the cost-effectiveness analysis and new program screening.
Table DSM-2 shows the results of averaging forward marginal energy prices over the 20-year planning
period that were determined as a result of the IRP planning process and selection of the preferred
portfolio. The alternate cost prices for energy efficiency measures that have a life longer than the 20-year planning horizon, which is typical for weatherization and building shell measures, are escalated at 2.2 percent annually beyond the planning period.
Demand-Side Resource Data Idaho Power Company
Page 74 2015 Integrated Resource Plan—Appendix C
Tables DSM-3 and DSM-4 show the distribution of the three summer and two non-summer pricing
periods across the hours and days of the week and for holidays.
Tables DSM-5 and DSM-6 lists the 20-year cumulative forecasted impact of average energy (aMW) and
on-peak reduction (MW) by customer class.
Table DSM-7 details the 20-year estimated utility or program administrator costs to support the
achievable potential forecast by customer class.
Table DSM-8 details the 20-year estimated TRC that accounts for both program administration costs and
incremental costs to acquire efficient measures and equipments by customers listed by customer class.
Table DSM-9 outlines the 20-year flow of total benefits attributed to energy efficiency programs including NEB associated with the forecast.
Table DSM-10 summarizes the cost-effectiveness analysis for energy efficiency programs through
the 20-year IRP planning period.
Table DSM-1. IRP financial assumptions
Avoided 30-Year Levelized Capacity Costs
SCCT ................................................................................................................................................................$119/kW
Financial Assumptions
Weighted average cost of capital (2014 year ending after tax) ................................................................6.74%
Financial escalation factor ................................................................................................................................2.20%
Transmission Losses
Non-summer secondary losses ................................................................................................................................9.60%
Summer peak loss ................................................................................................................................9.70%

Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 75
Table DSM-2. DSM alternate costs by pricing period
Year Summer On-Peak (SONP) Summer Mid-Peak (SMP) Summer Off-Peak (SOFP) Non-Summer Mid-Peak (NSMP) Non-Summer Off-Peak (NSOFP)
2015 $62.94 $44.84 $39.58 $31.67 $25.98
2016 $59.05 $40.44 $31.86 $33.75 $27.20
2017 $59.90 $39.64 $29.55 $35.44 $28.21
2018 $65.19 $43.78 $31.37 $38.82 $30.39
2019 $69.96 $43.83 $32.20 $38.74 $30.94
2020 $72.48 $42.68 $36.40 $38.06 $30.90
2021 $75.10 $47.16 $39.39 $41.11 $33.13
2022 $77.01 $49.12 $41.30 $43.02 $34.72
2023 $80.16 $51.53 $46.42 $44.43 $36.23
2024 $82.91 $53.18 $46.25 $46.27 $38.89
2025 $85.45 $48.50 $40.63 $47.50 $40.33
2026 $85.22 $51.66 $42.84 $48.75 $42.18
2027 $86.54 $53.57 $44.94 $49.64 $43.66
2028 $89.52 $55.95 $46.56 $51.45 $45.72
2029 $93.32 $59.08 $49.66 $53.69 $48.05
2030 $98.68 $64.01 $53.60 $56.72 $51.40
2031 $103.53 $64.37 $56.15 $58.55 $53.88
2032 $106.22 $66.04 $58.74 $61.52 $56.57
2033 $110.98 $71.21 $63.23 $64.96 $60.09
2034 $119.66 $78.44 $67.91 $68.39 $62.98
* Estimated average annual variable operations and management costs of a 170 MW capacity SCCT.

Demand-Side Resource Data Idaho Power Company
Page 76 2015 Integrated Resource Plan—Appendix C
Table DSM-3. DSM alternate cost summer pricing periods (June 1–August 31)
Hour Sunday Monday Tuesday Wednesday Thursday Friday Saturday Holiday
1 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
2 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
3 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
4 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
5 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
6 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
7 SMP SMP SMP SMP SMP SMP SMP SMP
8 SMP SMP SMP SMP SMP SMP SMP SMP
9 SMP SMP SMP SMP SMP SMP SMP SMP
10 SMP SMP SMP SMP SMP SMP SMP SMP
11 SMP SMP SMP SMP SMP SMP SMP SMP
12 SMP SMP SMP SMP SMP SMP SMP SMP
13 SMP SONP SONP SONP SONP SONP SMP SMP
14 SMP SONP SONP SONP SONP SONP SMP SMP
15 SMP SONP SONP SONP SONP SONP SMP SMP
16 SMP SONP SONP SONP SONP SONP SMP SMP
17 SMP SONP SONP SONP SONP SONP SMP SMP
18 SMP SONP SONP SONP SONP SONP SMP SMP
19 SMP SONP SONP SONP SONP SONP SMP SMP
20 SMP SONP SONP SONP SONP SONP SMP SMP
21 SMP SMP SMP SMP SMP SMP SMP SMP
22 SMP SMP SMP SMP SMP SMP SMP SMP
23 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP
24 SOFP SOFP SOFP SOFP SOFP SOFP SOFP SOFP

Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 77
Table DSM-4. DSM alternate cost non-summer pricing periods (September 1–May 31)
Hour Sunday Monday Tuesday Wednesday Thursday Friday Saturday Holiday
1 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
2 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
3 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
4 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
5 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
6 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
7 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
8 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
9 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
10 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
11 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
12 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
13 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
14 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
15 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
16 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
17 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
18 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
19 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
20 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
21 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
22 NSOFP NSMP NSMP NSMP NSMP NSMP NSMP NSOFP
23 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP
24 NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP NSOFP

Demand-Side Resource Data Idaho Power Company
Page 78 2015 Integrated Resource Plan—Appendix C
Table DSM-5. Cumulative existing energy efficiency forecast 2015–2034 (aMW w/transmission losses)
Year Residential Commercial/Industrial/
2015 ................................3 8 1 12
2016 ................................8 17 3 27
2017 ................................14 26 4 45
2018 ................................21 35 9 65
2019 ................................28 46 11 84
2020 ................................33 55 13 101
2021 ................................38 64 15 117
2022 ................................43 74 17 134
2023 ................................49 83 19 152
2024 ................................55 93 22 169
2025 ................................61 102 22 185
2026 ................................67 111 22 200
2027 ................................73 120 22 215
2028 ................................79 129 22 231
2029 ................................85 138 23 246
2030 ................................91 144 23 257
2031 ................................96 150 23 269
2032 ................................101 156 23 280
2033 ................................106 161 23 290
2034 ................................111 167 23 301

Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 79
Table DSM-6. Cumulative Energy Efficiency On-Peak Forecast 2015–2034
Year Residential Commercial/Industrial/ Special Contracts Irrigation Total
2015 ................................3 13 4 21
2016 ................................9 18 8 35
2017 ................................16 36 13 65
2018 ................................22 56 25 103
2019 ................................17 75 34 126
2020 ................................41 87 41 168
2021 ................................54 66 49 169
2022 ................................55 79 51 185
2023 ................................66 114 60 240
2024 ................................34 149 69 252
2025 ................................67 160 71 299
2026 ................................93 170 70 333
2027 ................................118 121 73 311
2028 ................................107 187 71 366
2029 ................................120 209 68 397
2030 ................................58 227 72 357
2031 ................................114 233 75 422
2032 ................................176 156 75 408
2033 ................................187 162 76 425
2034 ................................175 226 72 473

Demand-Side Resource Data Idaho Power Company
Page 80 2015 Integrated Resource Plan—Appendix C
Table DSM-7. Energy Efficiency Total Utility (Program Administrator) Costs 2015–2034 ($000s)
Year Residential Commercial/Industrial/ Special Contracts Irrigation Total
2015 ................................$7,055 $9,469 $1,467 $17,991
2016 ................................$9,976 $10,289 $1,509 $21,773
2017 ................................$12,738 $11,386 $1,529 $25,653
2018 ................................$13,667 $11,539 $4,878 $30,085
2019 ................................$14,999 $13,288 $2,501 $30,787
2020 ................................$13,339 $12,356 $2,527 $28,221
2021 ................................$14,535 $12,302 $2,576 $29,413
2022 ................................$16,012 $12,806 $2,700 $31,518
2023 ................................$17,772 $13,611 $2,813 $34,197
2024 ................................$18,220 $13,886 $2,902 $35,009
2025 ................................$18,358 $12,850 $229 $31,438
2026 ................................$18,771 $13,405 $232 $32,408
2027 ................................$19,463 $13,776 $267 $33,506
2028 ................................$20,865 $14,197 $260 $35,322
2029 ................................$20,510 $14,352 $252 $35,114
2030 ................................$18,994 $9,813 $228 $29,035
2031 ................................$18,935 $9,602 $266 $28,803
2032 ................................$18,928 $9,742 $264 $28,934
2033 ................................$18,862 $9,550 $272 $28,684
2034 ................................$18,719 $10,081 $197 $28,998
20-Year NPV $165,579 $128,817 $18,449 $312,845

Idaho Power Company Demand-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 81
Table DSM-8. Energy Efficiency Total Resource Costs 2015–2034 ($000s)
Year Residential Commercial/Industrial/ Special Contracts Irrigation Total
2015 ................................$16,326 $18,669 $11,067 $46,061
2016 ................................$29,583 $20,286 $11,385 $61,254
2017 ................................$38,737 $22,450 $11,533 $72,720
2018 ................................$42,651 $22,751 $36,805 $102,207
2019 ................................$42,679 $26,199 $18,868 $87,746
2020 ................................$30,400 $24,361 $19,067 $73,829
2021 ................................$34,094 $24,255 $19,435 $77,784
2022 ................................$38,590 $25,249 $20,369 $84,208
2023 ................................$42,024 $26,837 $21,228 $90,089
2024 ................................$42,358 $27,379 $21,898 $91,635
2025 ................................$47,611 $25,336 $1,731 $74,678
2026 ................................$46,892 $26,430 $1,752 $75,074
2027 ................................$48,215 $27,161 $2,016 $77,391
2028 ................................$52,314 $27,992 $1,958 $82,264
2029 ................................$50,857 $28,297 $1,900 $81,054
2030 ................................$46,970 $19,348 $1,722 $68,040
2031 ................................$47,774 $18,931 $2,009 $68,714
2032 ................................$46,959 $19,208 $1,994 $68,161
2033 ................................$47,981 $18,830 $2,051 $68,862
2034 ................................$44,098 $19,877 $1,486 $65,461
20-Year NPV $425,360 $253,982 $139,206 $818,548

Demand-Side Resource Data Idaho Power Company
Page 82 2015 Integrated Resource Plan—Appendix C
Table DSM-9. Total Energy Efficiency Benefits 2015–2034 ($000s)
Year Residential Commercial/Industrial/ Special Contracts Irrigation Total
2015 ................................$21,699 $36,952 $14,660 $73,310
2016 ................................$38,766 $38,720 $14,574 $92,061
2017 ................................$49,147 $41,059 $14,219 $104,426
2018 ................................$52,146 $52,256 $43,698 $148,101
2019 ................................$49,827 $47,230 $21,487 $118,544
2020 ................................$33,160 $42,650 $20,917 $96,727
2021 ................................$35,039 $40,544 $20,306 $95,888
2022 ................................$37,416 $40,278 $20,249 $97,943
2023 ................................$38,390 $40,571 $20,011 $98,971
2024 ................................$36,462 $39,329 $19,573 $95,364
2025 ................................$38,695 $27,735 $1,465 $67,895
2026 ................................$35,732 $27,415 $1,403 $64,550
2027 ................................$34,540 $26,725 $1,526 $62,790
2028 ................................$35,273 $26,015 $1,401 $62,690
2029 ................................$32,236 $24,768 $1,283 $58,287
2030 ................................$27,963 $15,185 $1,097 $44,244
2031 ................................$26,665 $13,946 $1,204 $41,814
2032 ................................$24,523 $13,256 $1,121 $38,901
2033 ................................$23,395 $12,098 $1,081 $36,574
2034 ................................$20,077 $11,902 $734 $32,712
20-Year NPV $691,151 $618,633 $222,009 $1,531,793

Table DSM-10. Total energy efficiency cost-effectiveness summary
2034 Load Reduction Utility Costs ($000s) Resource Costs ($000s) Total Benefits ($000s) TRC: Benefit/ TRC Levelized Costs
Residential 111 $165,579 $425,360 $691,151 1.6 9.8
Industrial/Commercial/Special Contract 167 $128,817 $253,982 $618,633 2.4 3.3
Irrigation 23 $18,449 $139,206 $222,009 1.6 10.3
Total 301 $312,845 $818,548 $1,531,793 1.9 6.1

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 83
SUPPLY-SIDE RESOURCE DATA
Key Financial and Forecast Assumptions
Composition
Debt ................................................................................................................................................................50.04%
Preferred ................................................................................................................................................................0.00%
Common ................................................................................................................................................................49.96%
Total ................................................................................................................................................................ 100.00%
Cost
Debt ................................................................................................................................................................5.73%
Preferred ................................................................................................................................................................0.00%
Common ................................................................................................................................................................10.00%
Average Weighted Cost ................................................................................................................................7.86%

Financial Assumptions and Factors
Plant operating (book) life ................................................................................................Expected Life of the Asset
Discount rate (weighted average cost of capital ) ................................................................................................6.74%
Composite tax rate ................................................................................................................................39.10%
Deferred rate ................................................................................................................................................................35.00%
General O&M escalation rate ................................................................................................................................2.20%
Annual property tax rate (% of investment) ................................................................................................0.29%
Property tax escalation rate ................................................................................................................................3.00%
Annual insurance premiums (% of investment) ................................................................................................0.31%
Insurance escalation rate ................................................................................................................................2.00%
AFUDC rate (annual) ................................................................................................................................7.75%
Incorporates tax effects.

Emission Intensity Rate (lbs per MWh by technology)
CO2
Small aeroderivative SCCT ................................................................................................................................1,115
Large aeroderivative SCCT ......................................................................................................................................1,047
Large frame SCCT ................................................................................................................................1,413
CCCT 1x1 ................................................................................................................................................................809
CCCT 2x1 ................................................................................................................................................................809
Combined heat and power (CHP) ............................................................................................................................1,115
Distributed generation–gas fired ..............................................................................................................................1,115
Pulverized coal ................................................................................................................................1,901
IGCC ................................................................................................................................................................2,279
IGCC w/carbon sequestration ................................................................................................................................421

Supply-Side Resource Data Idaho Power Company
Page 84 2015 Integrated Resource Plan—Appendix C
Fuel Forecast Base Case (Nominal, $ per MMBtu)
Year Natural Gas Generic Coal Nuclear
2015 ................................................................................................$5.10 $1.47 $0.51
2016 ................................................................................................$4.70 $1.52 $0.52
2017 ................................................................................................$4.76 $1.55 $0.53
2018 ................................................................................................$5.25 $1.58 $0.54
2019 ................................................................................................$5.69 $1.61 $0.56
2020 ................................................................................................$5.91 $1.64 $0.57
2021 ................................................................................................$6.14 $1.69 $0.58
2022 ................................................................................................$6.30 $1.74 $0.59
2023 ................................................................................................$6.58 $1.78 $0.61
2024 ................................................................................................$6.82 $1.83 $0.62
2025 ................................................................................................$7.04 $1.87 $0.63
2026 ................................................................................................$6.99 $1.91 $0.65
2027 ................................................................................................$7.09 $1.98 $0.66
2028 ................................................................................................$7.35 $2.00 $0.68
2029 ................................................................................................$7.69 $2.07 $0.69
2030 ................................................................................................$8.18 $2.12 $0.71
2031 ................................................................................................$8.62 $2.16 $0.72
2032 ................................................................................................$8.85 $2.21 $0.74
2033 ................................................................................................$9.28 $2.27 $0.75
2034 ................................................................................................$10.09 $2.32 $0.77
2035 ................................................................................................$10.15 $2.34 $0.79
2036 ................................................................................................$10.21 $2.35 $0.81
2037 ................................................................................................$10.27 $2.37 $0.82
2038 ................................................................................................$10.33 $2.38 $0.83
2039 ................................................................................................$10.39 $2.39 $0.83
2040 ................................................................................................$10.46 $2.41 $0.84
2041 ................................................................................................$10.52 $2.42 $0.84
2042 ................................................................................................$10.58 $2.44 $0.85
2043 ................................................................................................$10.65 $2.45 $0.85
2044 ................................................................................................$10.71 $2.47 $0.86

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 85
Cost Inputs and Operating Assumptions
(All costs in 2015 dollars)
Supply-Side Resources
Plant Capacity (MW)
Plant Capital ($/kW)1,3 Capital $/kW
Total Capital $/kW
Total Investment $/kW2
Fixed O&M $/kW3
Variable O&M $/kW Other $/MWh
Heat Rate Btu/kWh Life
Advanced Nuclear (250 MW) 1,100 4,350 441 $4,791 $7,266 95 0 0 10,450 40
Battery Storage (6 MW) 6 3,000 0 $3,000 $3,059 28 0 0 NA 10
Biomass Direct—Woody Residue (35 MW) 35 2,622 357 $2,979 $3,189 95 15 0 14,500 30
Biomass Indirect—Anaerobic Digester (3 MW) 3 4,761 133 $4,894 $5,239 43 14 0 10,250 25
Boardman to Hemingway (350 MW) 350 0 703 $703 $703 0 0 0 NA 55
Canal Drop Hydro (1.28 MW) 1 3,600 70 $3,670 $4,371 20 0 0 NA 75
CCCT (1x1) F Class with Duct Firing (270 MW) 270 1,145 122 $1,267 $1,484 8 2 0 6,714 30
CCCT (2x1) F Class (580 MW) 580 899 101 $1,000 $1,172 6 4 0 6,700 30
CHP (45 MW) 45 2,123 57 $2,180 $2,334 47 5 0 6,060 40
IGCC (580 MW) 580 3,257 745 $4,002 $4,773 62 7 0 8,800 35
IGCC with Carbon Capture (580 MW) 580 6,390 744 $7,134 $8,510 73 9 0 10,520 35
Geothermal (30 MW) 30 4,021 850 $4,871 $5,402 0 30 0 NA 25
ICE Thermal Storage (10 MW) 10 1,500 0 $1,500 $1,529 30 0 0 NA 20
Pumped Storage (150 MW) 150 5,000 1,095 $6,095 $7,259 20 0 0 NA 50
Reciprocating Gas Engine (18.8 MW) 19 500 73 $573 $610 2 4 0 7,329 40
SCCT—Aeroderivative (47 MW) 47 1,000 46 $1,046 $1,114 25 8 0 9,000 35
SCCT—Frame F Class (170 MW) 170 800 194 $994 $1,059 5 5 0 10,300 35
Shoshone Falls Upgrade (49.5 MW) 50 2,255 269 $2,524 $2,825 2 0 0 NA 75
Small Modular Nuclear (250 MW) 600 5,000 520 $5,520 $8,371 0 23 0 11,493 40
Solar Power Tower (110 MW) 110 6,250 330 $6,580 $7,710 82 3 6 NA 20
Solar PV—Distr Residential Fixed S (10 MW) 10 3,500 0 $3,500 $3,639 25 0 6 NA 20
Solar PV—Distr C&I Fixed S (10 MW) 10 2,500 0 $2,500 $2,599 13 0 6 NA 20
Solar PV—Distr C&I Fixed SW (10 MW) 10 2,500 0 $2,500 $2,599 13 0 6 NA 20
Solar PV—Utility Scale Fixed S (10 MW) 10 1,500 305 $1,805 $1,877 13 0 6 NA 20
Solar PV—Utility Scale Fixed SW (10 MW) 10 1,500 305 $1,805 $1,877 13 0 6 NA 20
Solar PV—Utility Scale 1-Axis Tracking (10 MW)10 1,750 305 $2,055 $2,136 20 0 6 NA 20
Solar PV—Utility Scale 2-Axis Tracking (10 MW)10 1,860 305 $2,165 $2,251 24 0 6 NA 20
TurboPhase (23.6 MW) 24 400 0 $400 $403 0 4 0 7,824 35
Wind (100 MW) 100 1,800 330 $2,130 $2,276 40 0 15 NA 25
1 Plant costs include engineering development costs, generating and ancillary equipment purchase, and installation costs, as well as balance of plant construction.
2 Total Investment includes capital costs and AFUDC.
3 Fixed O&M excludes property taxes and insurance (separately calculated within the levelized resource cost analysis)

Supply-Side Resource Data Idaho Power Company
Page 86 2015 Integrated Resource Plan—Appendix C
Transmission Cost Assumptions
Cost Assumptions by Supply-Side Resource Type
Capacity (MW Rating)
Overnight Transmission Capital Cost/kW1 Cost Assumptions Notes Local Interconnection Assumptions Backbone Transmission Assumptions
Battery Storage
6 $0 Assume location in or near existing substation. No transmission upgrades required. No backbone upgrades required.
Biomass Direct—Woody Residue
35 $357 Assume a 20-mile, 138-kV line to existing Idaho Power 138-kV substation. Add 3 new 138-kV terminals. Assume $250k in communications upgrades.
Assume a 20-mile, 138-kV line interconnection to existing Idaho Power 138-kV substation. Add 3 new 138-kV terminals. Assume $250k in communications upgrades.
No backbone upgrades required.
Biomass Indirect—Anaerobic Digester
3 $133 Assume distribution feeder location with no backbone transmission upgrades required.
Assume $300k of distribution feeder upgrades and $100k in substation upgrades.
No backbone upgrades required.
Coal—Integrated Gasification Combined Cycle (IGCC)
580 $745 Assume resource is located close to future 500-kV Aeolus substation. Pro-rated share of 3000 MW Gateway West project, with estimated toal cost of $2.19 billion.
Assume resource is located close to future 500-kV Aeolus substation. Assume 2 new terminals at 500-kV substation.
Pro-rata share of Gateway.
Coal—IGCC with Carbon Capture and Sequestration
600 $744 Assume resource is located close to future 500-kV Aeolus substation. Pro-rated share of 3000 MW Gateway West project, with estimated toal cost of $2.19 billion .
Assume resource is located close to future 500-kV Aeolus substation. Assume 2 new terminals at 500-kV substation.
Pro-rata share of Gateway.
Geothermal (binary-cycle)—Idaho
30 $850 Assume Raft River area. Requires 45-mile, 138-kV line to existing Minidoka substation. Assume capacity fits on existing backbone.
New 45-mile, 138-kV line to Minidoka substation with new 138-kV substation line terminal bay.
No backbone upgrades required.
Hydro—Canal Drop (Seasonal)
10 $70 Assume 46-kV sub-transmission or local feeder interconnection. Feeder rebuild or 46-kV upgrade would likely be required.
Assume 4 miles of distribution rebuild at $150k per mile plus $100k in substation upgrades.
No backbone upgrades required.
Hydro—Shoshone Falls Expansion
50 $269 Line and station modifications required. New substation above
existing power plant.
Assume $2 million for transmission line modifications, $7 million for
station upgrades, and $4.3 million for Cliff substation modifications.
Part of Generation Interconnect Cluster Study. No further backbone
upgrades required.
Hydro—Hydrokinetic (In stream)
1 $100 Assume minor upgrades required to distribution feeder or substation. Assume $100k in substation upgrades. No backbone upgrades required.
ICE Thermal Storage
10 $0 No transmission upgrades required. No transmission upgrades required. No backbone upgrades required.
Natural Gas—Simple Cycle Combustion Turbine (SCCT) Aeroderivative
47 $46 Assume plant located at or near existing Bennett Mountain plant. Capacity would fit within existing transmission system between Bennett Mountain and Boise.
New 230-kV substation terminal and station modifications. No backbone upgrades required.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 87
Capacity (MW Rating)
Overnight Transmission Capital Cost/kW1 Cost Assumptions Notes Local Interconnection Assumptions Backbone Transmission Assumptions
Natural Gas—SCCT Frame F Class (Idaho Power's peaker plants use this technology)
170 $194 Build new facility south of Boise (assume Simco Road area) with new 230-kV switching station; 22-mile, 230-kV line to Boise Bench Substation, and 230-kV double circuit in/out of Danskin–Hubbard 230-kV line.
New 230-kV switching station with a 22-mile, 230-kV line to Boise Bench Substation and 1 mile, 23-kV double circuit in/out of Danksin–Hubbard 230-kV line.
No backbone upgrades required.
Natural Gas—Reciprocating Gas Engine Wartsila 34SG
4.1 $73 Assume distribution feeder location
with no backbone transmission upgrades required.
Assume $300k of distribution feeder upgrades. No backbone upgrades required.
Natural Gas—CCCT (1x1) F Class with Duct Firing
270 $122 Build new facility south of Boise (assume Simco Road area) with new 230-kV switching station; 22-mile, 230-kV line to Boise Bench Substation, and 230-kV double circuit in/out of Danskin–Hubbard 230-kV line.
New 230-kV switching station with a 22-mile, 230-kV line to Boise Bench Substation and 1 mile, 23-kV double circuit in/out of Danksin–Hubbard 230-kV line.
No backbone upgrades required.
Natural Gas—CCCT (2x1) F Class
580 $101 Build new facility south of Boise (assume Simco Road area) with new 230-kV switching station; 22-mile, 230-kV line to Boise Bench Substation, and 230-kV double circuit in/out of Danskin–Hubbard 230-kV line.
New 230-kV switching station with a 22-mile; 230-kV line to Boise Bench Substation and 28-mile, 230-kV line to Hubbard Substation.
No backbone upgrades required. Entire project assumed as backbone upgrade.
Natural Gas—Combined Heat and Power (CHP)
45 $57 Assume 0.5 mile tap to existing 138-kV line and new 138-kV
source substation (or large upgrade to existing substation).
Assume 0.5 mile tap to existing 138-kV line and new 138-kV source substation.
No backbone upgrades required.
Nuclear—Small Modular Reactor (SMR)
45 $358 Tie into nearby 230-kV transmission substation. Backbone transmission uprgrades required.
Assume 2 mile, 138-kV interconnection to existing Antelope substation and one new 138-kV terminal.
Pro rata share of Gateway West upgrade from Populus to Cedar Hill to Hemingway. Assume 2.5% ownership of the 280-mile Gateway West segments from Populus to Cedar Hill and Cedar Hill to Hemingway.
Nuclear—SMR
250 $520 Tie into nearby 230-kV transmission substation. Build new 55 mile, 230-kV line. Backbone transmission uprgrades required.
Two 2-mile, 138-kV lines to interconnect to Antelope Substation. New 230-kV transformer terminal. New parallel 55-mile, 230-kV line from Antelope to Brady Substation. New 230-kV terminal at Brady Substation.
Pro rata share of Gateway West upgrade from Populus to Cedar hill to Hemingway. Assume 12.5% ownership of the 280-mile Gateway West segments from Populus to Cedar Hill and Cedar Hill to Hemingway.
Nuclear—Advanced Nuclear
1,100 $441 Two new 345kV transmission lines
required. One 55 mile line from site to Borah Substation. One 85 mile line from site to Kinport Substation via Goshen Substation.
New 345 kV station. New 55 mile
345kV transmission line to existing Borah substation and new 345kV line terminal. New 85 mile transmission line to existing Kinport Substation through existing Goshen Substation and three new 345 kV line terminals.
Pro rata share of Gateway West
upgrade from Populus to Cedar hill to Hemingway. Assume 50% ownership of the 280 mile Gateway West segments from Populus to Cedar Hill and Cedar Hill to Hemingway.
Pumped Storage—new upper reservoir and new generation/pumping plant (pumping water from an existing lower reservoir to a new upper reservoir then running the water through a new power plant)
100 $1,095 Tie into existing Oxbow 230-/ 138-kV switchyard. New 230-kV transmission line required from Oxbow to Treasure Valley (no existing backbone capacity).
Assume 0.5 mile tap off of Oxbow 138-kV line. New 110 mile, 230-kV line from Oxbow to Treasure Valley.

Supply-Side Resource Data Idaho Power Company
Page 88 2015 Integrated Resource Plan—Appendix C
Capacity (MW Rating)
Overnight Transmission Capital Cost/kW1 Cost Assumptions Notes Local Interconnection Assumptions Backbone Transmission Assumptions
Solar Thermal—Solar Power Tower with storage
100 $330 Assume Mountain Home desert area with 20-mile, 138-kV line to new substation intersecting existing Danskin—Hubbard 230-kV line.
New 230-kV switching station with a 22-mile, 230-kV line to Boise Bench Substation and 1-mile, 230-kV double circuit in/out of Danskin–Hubbard 230-kV line.
No backbone upgrades required.
Solar PV—Distributed Residential Fixed-Tilt (S Orientation)
10 $0 Assume that no upgrades are required for small residential installations.
Assume that no upgrades are required for small residential installations.
No backbone upgrades required.
Solar PV—Distributed C&I Fixed-Tilt (S Orientation)
10 $0 Assume that no upgrades are required for small C&I installations. Assume that no upgrades are required for small C&I installations. No backbone upgrades required.
Solar PV—Distributed C&I Fixed-Tilt (SW Orientation)
10 $0 Assume that no upgrades are required for small C&I installations. Assume that no upgrades are required for small C&I installations. No backbone upgrades required.
Solar PV—Utility Scale Fixed-Tilt (S Orientation)
10 $305 Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250k communication infrastructure upgrades.
Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250 communication infrastructure upgrades.
Assume that no backbone upgrades are required for 10 MW (depending on point in time, assumption may not be valid if PURPA projects are constructed in the same geographic area).
Solar PV—Utility Scale Fixed-Tilt (SW Orientation)
10 $305 Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250k communication infrastructure upgrades.
Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250 communication infrastructure upgrades.
Assume that no backbone upgrades are required for 10 MW (depending on point in time, assumption may not be valid if PURPA projects are constructed in the same geographic area).
Solar PV—Utility Scale 1-Axis Tracking
10 $305 Assume 1 mile, 138-kV
interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250k communication infrastructure upgrades.
Assume 1 mile, 138-kV
interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250 communication infrastructure upgrades.
Assume that no backbone
upgrades are required for 10 MW (depending on point in time, assumption may not be valid if PURPA projects are constructed in the same geographic area).
Solar PV—Utility Scale 2-Axis Tracking
10 $305 Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250k communication infrastructure upgrades.
Assume 1 mile, 138-kV interconnection to existing 138-kV transmission line. One 138-kV line terminal. Assume $250 communication infrastructure upgrades.
Assume that no backbone upgrades are required for 10 MW (depending on point in time, assumption may not be valid if PURPA projects are constructed in the same geographic area).
Transmission—Boardman to Hemingway
Inbound
350—Average
500—Summer
350—Winter
$711 Per the B2H Funding Agreement, Idaho Power's share of the project is roughly 21.2% of total project cost. Assume approximately $16 million in B2H 230-kV integration costs.
New 230-kV transmission circuit from Hemingway Substation to Bowmont Substation. New 230-kV line from Bowmont Substation to Hubbard Substation and 138-kV line re-configuration.
Pro-rata share of B2H project.
Wind—Idaho
100 $330 Assume location near Midpoint Substation or Justice Substation. Estimated $1.5 million for upgrades at Midpoint or Justice Substation plus 100 MW pro-rata share of 2,000-MW Gateway West 500-kV project from Midpoint/Cedar Hill Substation to Hemingway Substation.
Assume 10 miles of 138-kV local transmission to project site with 138-kV substation and 138-/ 230-kV transformer.
Assume $1.5 million for upgrades at Midpoint Substation or Justice Substation. Assume 5% share of estimated $425 million Gateway West 500kV project from Midpoint/Cedar Hill Substation to Hemingway Substation.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 89
Levelized Cost of Production
30-Year Levelized Cost of Production (at stated capacity factors)
Supply-Side Resources Cost of Capital Non-Fuel O&M1 Fuel Wholesale Energy
Net of Tax Credit/Steam sales/Integration
Total Cost per MWh Capacity Factor
Advanced Nuclear (250 MW) $88 $25 $7 $0 $0 $119 90%
Battery Storage (6 MW) $216 $24 $0 $46 $0 $285 25%
Biomass Direct—Woody Residue (35 MW) $44 $40 $19 $0 $0 $102 85%
Biomass Indirect— Anaerobic Digester (3 MW) $87 $33 $0 $0 $0 $119 75%
Boardman to Hemingway (350 MW) $21 $2 $0 $54 $0 $78 33%
Canal Drop Hydro (1.28 MW) $135 $24 $0 $0 $0 $159 33%
CCCT (1x1) F Class with Duct Firing (270 MW) $25 $6 $49 $0 $0 $79 70%
CCCT (2x1) F Class (580 MW) $20 $7 $48 $0 $0 $75 70%
CHP (45 MW) $32 $19 $46 $0 -$16 $81 80%
IGCC (580 MW) $71 $28 $17 $0 $0 $116 75%
IGCC with Carbon Capture (580 MW) $127 $37 $21 $0 $0 $184 75%
Geothermal (30 MW) $64 $43 $0 $0 -$6 $101 90%
ICE Thermal Storage (10 MW) $171 $53 $0 $0 $0 $224 10%
Pumped Storage (150 MW) $304 $42 $0 $57 $0 $403 25%
Reciprocating Gas Engine (18.8 MW) $66 $14 $55 $0 $0 $136 10%
SCCT—Aeroderivative (47 MW) $124 $59 $67 $0 $0 $250 10%
SCCT—Frame F Class (170 MW) $118 $24 $76 $0 $0 $219 10%
Shoshone Falls Upgrade (49.5 MW) $66 $8 $0 $0 $0 $74 43%
Small Modular Nuclear (250 MW) $96 $39 $208 $0 $0 $343 95%
Solar Power Tower (110 MW) $325 $69 $0 $0 -$21 $372 28%
Solar PV—Distr Residential Fixed S (10 MW) $212 $33 $0 $0 -$11 $234 20%
Solar PV—Distr C&I Fixed S (10 MW) $148 $20 $0 $0 -$6 $162 21%
Solar PV—Distr C&I Fixed SW (10 MW) $155 $21 $0 $0 -$6 $170 20%
Solar PV—Utility Scale Fixed S (10 MW) $103 $16 $0 $0 -$2 $118 21%
Solar PV—Utility Scale Fixed SW (10 MW) $109 $17 $0 $0 -$2 $124 20%
Solar PV—Utility Scale 1-Axis Tracking (10 MW) $92 $17 $0 $0 -$1 $109 27%
Solar PV—Utility Scale 2-Axis Tracking (10 MW) $88 $18 $0 $0 $0 $105 30%
TurboPhase (23.6 MW) $45 $8 $58 $0 $0 $111 10%
Wind (100 MW) $86 $28 $0 $0 $21 $135 28%
1 Non Fuel O&M includes fixed and variable costs, property taxes.

Supply-Side Resource Data Idaho Power Company
Page 90 2015 Integrated Resource Plan—Appendix C
30-Year Levelized Capacity (fixed) Cost per kW/Month
Supply-Side Resources Cost of Capital Non-Fuel O&M Fuel
Net of Tax Credit/Steam sales/Integration Total Cost per kW
Advanced Nuclear (250 MW) $57 $16 $0 $0 $73
Battery Storage (6 MW) $39 $4 $0 $0 $44
Biomass Direct—Woody Residue (35 MW) $27 $12 $0 $0 $40
Biomass Indirect—Anaerobic Digester (3 MW) $48 $8 $0 $0 $55
Boardman to Hemingway (350 MW) $5 $1 $0 $0 $6
Canal Drop Hydro (1.28 MW) $32 $6 $0 $0 $38
CCCT (1x1) F Class with Duct Firing (270 MW) $13 $2 $0 $0 $14
CCCT (2x1) F Class (580 MW) $10 $1 $0 $0 $11
CHP (45 MW) $18 $7 $0 $0 $26
IGCC (580 MW) $39 $10 $0 $0 $49
IGCC with Carbon Capture (580 MW) $69 $14 $0 $0 $83
Geothermal (30 MW) $42 $0 $0 $0 $42
ICE Thermal Storage (10 MW) $13 $4 $0 $0 $17
Pumped Storage (150 MW) $55 $8 $0 $0 $63
Reciprocating Gas Engine (18.8 MW) $5 $1 $0 $0 $5
SCCT—Aeroderivative (47 MW) $9 $4 $0 $0 $13
SCCT—Frame F Class (170 MW) $9 $1 $0 $0 $10
Shoshone Falls Upgrade (49.5 MW) $21 $2 $0 $0 $23
Small Modular Nuclear (250 MW) $66 $6 $0 $0 $72
Solar Power Tower (110 MW) $66 $7 $0 $0 $73
Solar PV—Distr Residential Fixed S (10 MW) $31 $2 $0 $0 $33
Solar PV—Distr C&I Fixed S (10 MW) $22 $1 $0 $0 $23
Solar PV—Distr C&I Fixed SW (10 MW) $22 $1 $0 $0 $23
Solar PV—Utility Scale Fixed S (10 MW) $16 $1 $0 $0 $17
Solar PV—Utility Scale Fixed SW (10 MW) $16 $1 $0 $0 $17
Solar PV—Utility Scale 1-Axis Tracking (10 MW) $18 $2 $0 $0 $20
Solar PV—Utility Scale 2-Axis Tracking (10 MW) $19 $2 $0 $0 $21
TurboPhase (23.6 MW) $3 $0 $0 $0 $4
Wind (100 MW) $18 $6 $0 $0 $23

Peak-Hour Capacity Credit (Contribution to Peak)—Solar and
Wind Resources
Peak hour capacity credit (contribution to peak) for new IRP intermittent generation resources:
New IRP intermittent generation—Peak hour capacity credit
Resource Peak Hour Capacity Credit
PV solar south orientation 28.4%
PV solar southwest orientation 45.4%
PV solar single-axis tracking 51.3%
Wind 5.0%

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 91
Energy Shape—Solar
2015 IRP Assumed Solar Capacity Factors
Month Utility Scale, Single Axis Tracking Residential, Fixed Tilt
January 12% 7%
February 19% 11%
March 26% 16%
April 32% 20%
May 37% 23%
June 41% 25%
July 42% 26%
August 39% 24%
September 33% 20%
October 25% 16%
November 14% 9%
December 11% 7%
Annual Capacity Factor 27.5% 17.0%

Supply-Side Resource Data Idaho Power Company
Page 92 2015 Integrated Resource Plan—Appendix C
Schedule 87—Integration Costs for Solar and Wind Resources
Solar
0–100 MW Solar Capacity Penetration Level
Levelized Non Levelized
On-line Year 20-Year Contract Term Levelized Rates* Contract year Non-Levelized Rates*
2014 0.54 2014 0.43
2015 0.56 2015 0.44
2016 0.58 2016 0.46
2017 0.59 2017 0.47
2018 0.61 2018 0.48
2019 0.63 2019 0.50
2020 0.51
2021 0.53
2022 0.54
2023 0.56
2024 0.58
2025 0.60
2026 0.61
2027 0.63
2028 0.65
2029 0.67
2030 0.69
2031 0.71
2032 0.73
2033 0.75
2034 0.78
2035 0.80
2036 0.82
2037 0.85
2038 0.87
2039 0.90
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 93
101–200 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 1.49 2014 1.18
2015 1.53 2015 1.22
2016 1.58 2016 1.25
2017 1.63 2017 1.29
2018 1.68 2018 1.33
2019 1.73 2019 1.37
2020 1.41
2021 1.45
2022 1.50
2023 1.54
2024 1.59
2025 1.63
2026 1.68
2027 1.73
2028 1.79
2029 1.84
2030 1.89
2031 1.95
2032 2.01
2033 2.07
2034 2.13
2035 2.20
2036 2.26
2037 2.33
2038 2.40
2039 2.47
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 94 2015 Integrated Resource Plan—Appendix C

201–300 MW Solar Capacity Penetration Level
Levelized Non Levelized
On-line Year 20-Year Contract Term Levelized Rates* Contract year Non-Levelized Rates
2014 2.32 2014 1.84
2015 2.39 2015 1.89
2016 2.46 2016 1.95
2017 2.54 2017 2.01
2018 2.61 2018 2.07
2019 2.69 2019 2.13
2020 2.20
2021 2.26
2022 2.33
2023 2.40
2024 2.47
2025 2.55
2026 2.62
2027 2.70
2028 2.78
2029 2.87
2030 2.95
2031 3.04
2032 3.13
2033 3.23
2034 3.32
2035 3.42
2036 3.52
2037 3.63
2038 3.74
2039 3.85
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 95
301–400 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 3.12 2014 2.48
2015 3.22 2015 2.55
2016 3.32 2016 2.63
2017 3.41 2017 2.71
2018 3.52 2018 2.79
2019 3.62 2019 2.87
2020 2.96
2021 3.05
2022 3.14
2023 3.23
2024 3.33
2025 3.43
2026 3.53
2027 3.64
2028 3.75
2029 3.86
2030 3.97
2031 4.09
2032 4.22
2033 4.34
2034 4.47
2035 4.61
2036 4.75
2037 4.89
2038 5.03
2039 5.19
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 96 2015 Integrated Resource Plan—Appendix C
401–500 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 3.94 2014 3.12
2015 4.06 2015 3.22
2016 4.18 2016 3.31
2017 4.31 2017 3.41
2018 4.44 2018 3.52
2019 4.57 2019 3.62
2020 3.73
2021 3.84
2022 3.96
2023 4.08
2024 4.20
2025 4.32
2026 4.45
2027 4.59
2028 4.72
2029 4.87
2030 5.01
2031 5.16
2032 5.32
2033 5.48
2034 5.64
2035 5.81
2036 5.98
2037 6.16
2038 6.35
2039 6.54
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 97
501–600 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 4.76 2014 3.78
2015 4.91 2015 3.89
2016 5.05 2016 4.01
2017 5.21 2017 4.13
2018 5.36 2018 4.25
2019 5.52 2019 4.38
2020 4.51
2021 4.64
2022 4.78
2023 4.93
2024 5.07
2025 5.23
2026 5.38
2027 5.55
2028 5.71
2029 5.88
2030 6.06
2031 6.24
2032 6.43
2033 6.62
2034 6.82
2035 7.02
2036 7.24
2037 7.45
2038 7.68
2039 7.91
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 98 2015 Integrated Resource Plan—Appendix C
601–700 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 5.54 2014 4.39
2015 5.71 2015 4.53
2016 5.88 2016 4.66
2017 6.06 2017 4.80
2018 6.24 2018 4.95
2019 6.43 2019 5.09
2020 5.25
2021 5.40
2022 5.57
2023 5.73
2024 5.91
2025 6.08
2026 6.26
2027 6.45
2028 6.65
2029 6.85
2030 7.05
2031 7.26
2032 7.48
2033 7.70
2034 7.94
2035 8.17
2036 8.42
2037 8.67
2038 8.93
2039 9.20
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 99
701–800 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 6.70 2014 5.31
2015 6.91 2015 5.47
2016 7.11 2016 5.64
2017 7.33 2017 5.81
2018 7.55 2018 5.98
2019 7.77 2019 6.16
2020 6.35
2021 6.54
2022 6.73
2023 6.93
2024 7.14
2025 7.36
2026 7.58
2027 7.80
2028 8.04
2029 8.28
2030 8.53
2031 8.78
2032 9.05
2033 9.32
2034 9.60
2035 9.89
2036 10.18
2037 10.49
2038 10.80
2039 11.13
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Supply-Side Resource Data Idaho Power Company
Page 100 2015 Integrated Resource Plan—Appendix C
801–900 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 7.98 2014 6.32
2015 8.21 2015 6.51
2016 8.46 2016 6.71
2017 8.71 2017 6.91
2018 8.98 2018 7.11
2019 9.25 2019 7.33
2020 7.55
2021 7.77
2022 8.01
2023 8.25
2024 8.50
2025 8.75
2026 9.01
2027 9.28
2028 9.56
2029 9.85
2030 10.14
2031 10.45
2032 10.76
2033 11.08
2034 11.42
2035 11.76
2036 12.11
2037 12.48
2038 12.85
2039 13.24
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 101
901–1,000 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 9.52 2014 7.54
2015 9.80 2015 7.77
2016 10.10 2016 8.00
2017 10.40 2017 8.24
2018 10.71 2018 8.49
2019 11.03 2019 8.74
2020 9.01
2021 9.28
2022 9.55
2023 9.84
2024 10.14
2025 10.44
2026 10.75
2027 11.08
2028 11.41
2029 11.75
2030 12.10
2031 12.47
2032 12.84
2033 13.23
2034 13.62
2035 14.03
2036 14.45
2037 14.89
2038 15.33
2039 15.79
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Supply-Side Resource Data Idaho Power Company
Page 102 2015 Integrated Resource Plan—Appendix C
1,001–1,100 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 11.38 2014 9.02
2015 11.72 2015 9.29
2016 12.07 2016 9.56
2017 12.43 2017 9.85
2018 12.80 2018 10.15
2019 13.19 2019 10.45
2020 10.77
2021 11.09
2022 11.42
2023 11.76
2024 12.12
2025 12.48
2026 12.85
2027 13.24
2028 13.64
2029 14.05
2030 14.47
2031 14.90
2032 15.35
2033 15.81
2034 16.28
2035 16.77
2036 17.28
2037 17.79
2038 18.33
2039 18.88
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 103
1,101–1,200 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 13.61 2014 10.78
2015 14.01 2015 11.11
2016 14.43 2016 11.44
2017 14.87 2017 11.78
2018 15.31 2018 12.14
2019 15.77 2019 12.50
2020 12.88
2021 13.26
2022 13.66
2023 14.07
2024 14.49
2025 14.93
2026 15.37
2027 15.84
2028 16.31
2029 16.80
2030 17.30
2031 17.82
2032 18.36
2033 18.91
2034 19.48
2035 20.06
2036 20.66
2037 21.28
2038 21.92
2039 22.58
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Supply-Side Resource Data Idaho Power Company
Page 104 2015 Integrated Resource Plan—Appendix C
1,201–1,300 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 16.26 2014 12.89
2015 16.75 2015 13.28
2016 17.25 2016 13.67
2017 17.77 2017 14.08
2018 18.30 2018 14.51
2019 18.85 2019 14.94
2020 15.39
2021 15.85
2022 16.33
2023 16.82
2024 17.32
2025 17.84
2026 18.38
2027 18.93
2028 19.50
2029 20.08
2030 20.68
2031 21.30
2032 21.94
2033 22.60
2034 23.28
2035 23.98
2036 24.70
2037 25.44
2038 26.20
2039 26.99
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 105
1,301–1,400 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 19.40 2014 15.38
2015 19.98 2015 15.84
2016 20.58 2016 16.31
2017 21.20 2017 16.80
2018 21.84 2018 17.31
2019 22.49 2019 17.83
2020 18.36
2021 18.91
2022 19.48
2023 20.06
2024 20.66
2025 21.28
2026 21.92
2027 22.58
2028 23.26
2029 23.96
2030 24.67
2031 25.41
2032 26.18
2033 26.96
2034 27.77
2035 28.60
2036 29.46
2037 30.35
2038 31.26
2039 32.19
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Supply-Side Resource Data Idaho Power Company
Page 106 2015 Integrated Resource Plan—Appendix C
1,301–1,400 MW Solar Capacity Penetration Level**
Levelized Non Levelized
20-Year Contract Term
2014 23.07 2014 18.29
2015 23.77 2015 18.84
2016 24.48 2016 19.40
2017 25.21 2017 19.98
2018 25.97 2018 20.58
2019 26.75 2019 21.20
2020 21.84
2021 22.49
2022 23.17
2023 23.86
2024 24.58
2025 25.31
2026 26.07
2027 26.86
2028 27.66
2029 28.49
2030 29.35
2031 30.23
2032 31.13
2033 32.07
2034 33.03
2035 34.02
2036 35.04
2037 36.09
2038 37.18
2039 38.29
*$/MWh
**Integration costs for solar penetrations beyond 700 MW are not part of published Schedule 87 as of June 2015. These integration costs are based on an extrapolation of published integrated costs.

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 107
Wind
0–100 MW Wind Capacity Penetration Level
Levelized Non Levelized
On-line Year 20-Year Contract Term Levelized Rates* Contract year Non-Levelized Rates
2014 0.27 2014 0.21
2015 0.27 2015 0.22
2016 0.28 2016 0.23
2017 0.29 2017 0.23
2018 0.30 2018 0.24
2019 0.31 2019 0.25
2020 0.25
2021 0.26
2022 0.27
2023 0.28
2024 0.29
2025 0.29
2026 0.30
2027 0.31
2028 0.32
2029 0.33
2030 0.34
2031 0.35
2032 0.36
2033 0.37
2034 0.38
2035 0.40
2036 0.41
2037 0.42
2038 0.43
2039 0.45
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 108 2015 Integrated Resource Plan—Appendix C
101–200 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 1.22 2014 0.98
2015 1.25 2015 1.00
2016 1.29 2016 1.04
2017 1.33 2017 1.07
2018 1.37 2018 1.10
2019 1.41 2019 1.13
2020 1.16
2021 1.20
2022 1.24
2023 1.27
2024 1.31
2025 1.35
2026 1.39
2027 1.43
2028 1.48
2029 1.52
2030 1.57
2031 1.61
2032 1.66
2033 1.71
2034 1.76
2035 1.81
2036 1.87
2037 1.93
2038 1.98
2039 2.04
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 109

201–300 MW Wind Capacity Penetration Level
Levelized Non Levelized
On-line Year 20-Year Contract Term Levelized Rates* Contract year Non-Levelized Rates
2014 2.78 2014 2.23
2015 2.87 2015 2.30
2016 2.95 2016 2.37
2017 3.04 2017 2.44
2018 3.13 2018 2.51
2019 3.23 2019 2.59
2020 2.67
2021 2.75
2022 2.83
2023 2.92
2024 3.00
2025 3.09
2026 3.19
2027 3.28
2028 3.38
2029 3.48
2030 3.59
2031 3.69
2032 3.80
2033 3.92
2034 4.04
2035 4.16
2036 4.28
2037 4.41
2038 4.54
2039 4.68
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 110 2015 Integrated Resource Plan—Appendix C
301–400 MW Solar Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 4.95 2014 3.98
2015 5.10 2015 4.10
2016 5.26 2016 4.22
2017 5.41 2017 4.35
2018 5.58 2018 4.48
2019 5.74 2019 4.61
2020 4.75
2021 4.89
2022 5.04
2023 5.19
2024 5.34
2025 5.51
2026 5.67
2027 5.84
2028 6.02
2029 6.20
2030 6.38
2031 6.57
2032 6.77
2033 6.97
2034 7.18
2035 7.40
2036 7.62
2037 7.85
2038 8.08
2039 8.33
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 111
401–500 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 7.71 2014 6.19
2015 7.95 2015 6.38
2016 8.18 2016 6.57
2017 8.43 2017 6.77
2018 8.68 2018 6.97
2019 8.94 2019 7.18
2020 7.39
2021 7.62
2022 7.84
2023 8.08
2024 8.32
2025 8.57
2026 8.83
2027 9.09
2028 9.37
2029 9.65
2030 9.94
2031 10.23
2032 10.54
2033 10.86
2034 11.18
2035 11.52
2036 11.86
2037 12.22
2038 12.59
2039 12.96
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 112 2015 Integrated Resource Plan—Appendix C
501–600 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 11.05 2014 8.87
2015 11.38 2015 9.13
2016 11.72 2016 9.41
2017 12.07 2017 9.69
2018 12.43 2018 9.98
2019 12.81 2019 10.28
2020 10.59
2021 10.91
2022 11.23
2023 11.57
2024 11.92
2025 12.28
2026 12.64
2027 13.02
2028 13.41
2029 13.82
2030 14.23
2031 14.66
2032 15.10
2033 15.55
2034 16.02
2035 16.50
2036 16.99
2037 17.50
2038 18.03
2039 18.57
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 113
601–700 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 14.94 2014 11.99
2015 15.39 2015 12.35
2016 15.85 2016 12.72
2017 16.33 2017 13.10
2018 16.82 2018 13.50
2019 17.32 2019 13.90
2020 14.32
2021 14.75
2022 15.19
2023 15.65
2024 16.12
2025 16.60
2026 17.10
2027 17.61
2028 18.14
2029 18.68
2030 19.24
2031 19.82
2032 20.42
2033 21.03
2034 21.66
2035 22.31
2036 22.98
2037 23.67
2038 24.38
2039 25.11
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 114 2015 Integrated Resource Plan—Appendix C
701–800 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 19.38 2014 15.55
2015 19.96 2015 16.02
2016 20.56 2016 16.50
2017 21.17 2017 17.00
2018 21.81 2018 17.51
2019 22.46 2019 18.03
2020 18.57
2021 19.13
2022 19.70
2023 20.29
2024 20.90
2025 21.53
2026 22.18
2027 22.84
2028 23.53
2029 24.23
2030 24.96
2031 25.71
2032 26.48
2033 27.27
2034 28.09
2035 28.93
2036 29.80
2037 30.70
2038 31.62
2039 32.57
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 115
801–900 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 24.34 2014 19.54
2015 25.07 2015 20.13
2016 25.83 2016 20.73
2017 26.60 2017 21.35
2018 27.40 2018 21.99
2019 28.22 2019 22.65
2020 23.33
2021 24.03
2022 24.75
2023 25.50
2024 26.26
2025 27.05
2026 27.86
2027 28.70
2028 29.56
2029 30.44
2030 31.36
2031 32.30
2032 33.27
2033 34.26
2034 35.29
2035 36.35
2036 37.44
2037 38.56
2038 39.72
2039 40.91
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 116 2015 Integrated Resource Plan—Appendix C
901–1,000 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 29.82 2014 23.94
2015 30.72 2015 24.66
2016 31.64 2016 25.40
2017 32.59 2017 26.16
2018 33.57 2018 26.94
2019 34.57 2019 27.75
2020 28.59
2021 29.44
2022 30.33
2023 31.24
2024 32.17
2025 33.14
2026 34.13
2027 35.16
2028 36.21
2029 37.30
2030 38.42
2031 39.57
2032 40.76
2033 41.98
2034 43.24
2035 44.54
2036 45.87
2037 47.25
2038 48.66
2039 50.12
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 117
1,001–1,100 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 35.81 2014 28.74
2015 36.88 2015 29.60
2016 37.99 2016 30.49
2017 39.13 2017 31.41
2018 40.30 2018 32.35
2019 41.51 2019 33.32
2020 34.32
2021 35.35
2022 36.41
2023 37.50
2024 38.63
2025 39.78
2026 40.98
2027 42.21
2028 43.47
2029 44.78
2030 46.12
2031 47.51
2032 48.93
2033 50.40
2034 51.91
2035 53.47
2036 55.07
2037 56.72
2038 58.43
2039 60.18
*$/MWh

Supply-Side Resource Data Idaho Power Company
Page 118 2015 Integrated Resource Plan—Appendix C
1,101–1,200 MW Wind Capacity Penetration Level
Levelized Non Levelized
20-Year Contract Term
2014 42.27 2014 33.93
2015 43.54 2015 34.95
2016 44.85 2016 36.00
2017 46.19 2017 37.08
2018 47.58 2018 38.19
2019 49.01 2019 39.34
2020 40.52
2021 41.73
2022 42.98
2023 44.27
2024 45.60
2025 46.97
2026 48.38
2027 49.83
2028 51.33
2029 52.87
2030 54.45
2031 56.09
2032 57.77
2033 59.50
2034 61.29
2035 63.12
2036 65.02
2037 66.97
2038 68.98
2039 71.05
*$/MWh

Idaho Power Company Supply-Side Resource Data
2015 Integrated Resource Plan—Appendix C Page 119
PURPA Reference Data
The following information is provided for PURPA reference purposes.
1. Preferred portfolio: Portfolio P6(b)
Resource portfolio P6(b)
Date Resource Installed Capacity Peak-Hour Capacity
2025 B2H 500 MW transfer capacity April–Sep
200 MW transfer capacity Oct–Mar
500 MW
2025 Retire North Valmy (both units) (262 MW) (262 MW)
2031 CCCT 300 MW 300 MW

2. Deficiency period under preferred portfolio
1st capacity deficit = (14) MW July 2025
1st energy deficit = (34) MW July 2026
Note—Above deficits are based on 461 MW of installed PV solar capacity under contract at the
time of portfolio design, and do not reflect the April 2015 cancellation of 141 MW of PV solar
PURPA contracts. With removal of the 141 MW of PV solar PURPA contracts, the first deficits
for capacity and energy are respectively (47) MW in July 2024 and (76) MW in July 2026.
3. Intermittent generation integration costs
See integration cost schedule included in Appendix C—Technical Appendix, section
Schedule 87—Integration Costs for Solar and Wind Resources.

Supply-Side Resource Data Idaho Power Company
Page 120 2015 Integrated Resource Plan—Appendix C
Renewable Energy Certificate Price Forecast
Year Nominal ($/MWh)
2015 $3.04
2016 $3.06
2017 $3.95
2018 $3.95
2019 $4.70
2020 $5.23
2021 $5.48
2022 $5.73
2023 $5.98
2024 $6.33
2025 $6.68
2026 $7.05
2027 $7.45
2028 $7.83
2029 $8.22
2030 $8.64
2031 $9.06
2032 $9.49
2033 $9.93
2034 $10.38

Idaho Power Company Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis
2015 Integrated Resource Plan—Appendix C Page 121
JIM BRIDGER UNITS 3 AND 4 SELECTIVE CATALYTIC
REDUCTION ANALYSIS
The 2015 Jim Bridger Plant units 3 and 4 Selective Catalytic Reduction (SCR) Analysis (2015 SCR Analysis) is intended to satisfy the conditions set forth by the Idaho Public Utilities Commission (IPUC)
in Order No. 32929 approving the Certificate of Public Convenience and Necessity (CPCN) for the
investment in SCR controls on Jim Bridger units 3 and 4. Commission Order No. 32929 directs Idaho
Power to be “continuously analyzing the impact of changing environmental regulations on its upgrade
project.” (Order No. 32929, p. 11). In addition to the above requirement, the company files quarterly reports in Docket No. IPC-E-13-16 providing updates as to the current status of environmental policies
that are relevant to the construction of the SCR controls at Jim Bridger units 3 and 4, construction
progress updates, and any other pertinent updates related to the SCRs.
The company’s 2015 SCR Analysis evaluates the impacts of new environmental regulations proposed
since the company filed its Coal Unit Environmental Analysis in 2013 (2013 Coal Study) as well as the cost-effectiveness of continuing the installation of the SCRs compared to shutting down units 3 and 4
and replacing that generation with an alternate generation resource.
Background
The Jim Bridger coal-fired power plant (Jim Bridger Plant) consists of four units and is located near
Rock Springs, Wyoming. Idaho Power owns one-third of the Jim Bridger Plant with the other two-thirds
owned by PacifiCorp. The plant is maintained and operated by PacifiCorp. Units 3 and 4 have nominal
net generation capacities of 523 and 530 megawatts (MW) respectively, and Idaho Power’s share of the
generation capacity is approximately 351 MW from both units.
Currently, the Jim Bridger Plant is required to meet SCR-based emission limits of 0.07 lb/MMBtu for
nitrogen oxides (NOx) for all four units to comply with the U.S. Environmental Protection Agency
(EPA) Regional Haze (RH) rules and the resulting Wyoming State Implementation Plan (SIP). SCRs are
used to facilitate a chemical reaction between NOx (created during combustion) and ammonia to create
nitrogen and water.
In 2013, as part of the 2011 IRP Update, the company filed its 2013 Coal Study which examined future
investments required for environmental compliance in existing coal units and compared those
investments to the costs of alternative replacement resources. The results of the 2013 Coal Study
analysis for Jim Bridger identified additional investments in environmental controls on all four
Jim Bridger units as prudent decisions that represented the lowest cost and least-risk option when compared to the other investment alternatives. The company used the results of the 2013 Coal Study to
support its Application for approval of a CPCN for the investment in SCRs on units 3 and 4.
Subsequently, the IPUC issued its approval of the CPCN in December 2013 and construction of the
SCRs began shortly after.
SCR Construction Progress Update
The major components of an SCR upgrade consist of: large particle ash collection, ammonia injection
grid, the SCR reactor vessel (which contains the catalyst modules), and all added flue gas path
ductwork. In addition to the SCR, Unit 4 will require larger induced draft fans to compensate for the flow restriction of the SCR reactor.
Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis Idaho Power Company
Page 122 2015 Integrated Resource Plan—Appendix C
Construction of the SCRs is ongoing; as of May 2015, 99 percent of the 2,588 tons of the Unit 3
structural steel and 83 percent of the 7,570 linear feet of the SCR reactor piping has been completed.
For Unit 4, 63 percent of the 3,031 tons of structural steel has been completed.
The Unit 3 SCR is scheduled to be completed by November 5, 2015, with a Wyoming SIP compliance deadline of December 31, 2015. Unit 4 is scheduled for completion by November 3, 2016, with a
Wyoming SIP compliance date of December 31, 2016.
2015 Jim Bridger Units 3 and 4 SCR Analysis
The 2015 SCR Analysis re-examines the previous conclusion that installation of the SCRs on units 3 and
4 is the least-cost and least-risk means of ensuring that units 3 and 4 comply with state and federal
emissions regulations. The 2015 SCR Analysis had two objectives:
1. Evaluate changes in environmental requirements since the 2013 Coal Study that may have an
impact on the cost-effectiveness and/or viability of the SCRs on units 3 and 4, and
2. Determine the cost-effectiveness of installing the SCRs compared to the fixed costs of replacing
the coal-fired generation from units 3 and 4 with a combined-cycle combustion turbine (CCCT)
generation resource alternative.
Changes in Environmental Regulations
On June 2, 2014, the EPA released its draft proposal to regulate carbon dioxide (CO2) emissions from
existing power plants. In the rule, the EPA proposes enforceable CO2 performance goals that are based on a bottom-up, multi-factor analysis that reflects a system-wide approach of four building blocks, including increasing efficiency of the existing coal-fired generation, natural gas re-dispatch,
renewable energy deployment, and demand-side energy efficiency. The goals take the form of
state-wide carbon intensity rates for the state’s electric power sector. Each state’s goal reflects an
emissions target (stated as lbs of CO2/MWh of generation) that EPA has determined to be reasonable based upon the theoretical application of the “best system of emission reduction” for fossil-fueled power plants.
The proposal directs states to submit plans for meeting their goals. States may also work together to
submit a single, coordinated multi-state plan. States and multi-state groups have a June 2016 deadline
for submitting their plans, with the possibility of a 1- or 2-year extension depending on the plan type. Under the proposed rule, each state’s plan must be approved by the EPA, based on modeling projections by the state that demonstrate, to the agency’s satisfaction, that the plan will be adequate to meet EPA’s
determination of the state’s interim and final goals. State plans do not need to rely upon the
four building block measures EPA used to construct each state’s goal. Rather, each state has relatively
broad discretion to determine the policy measures on which it will rely to meet its goal.
There are several alternative approaches to 111(d) compliance. The individual states where the generators are physically located will determine the final impact to each of the affected units.
Idaho Power has reviewed the Wyoming intensity targets and alternative approaches to compliance,
and the company believes that there will be minimal impact on the normal operation of Jim Bridger
units 3 and 4.
Idaho Power Company Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis
2015 Integrated Resource Plan—Appendix C Page 123
SCR Cost-Effectiveness
To determine if the SCRs on units 3 and 4 continue to be the least-cost and least-risk option for
compliance, the 2015 SCR Analysis compared the costs of two compliance options:
Option 1—Continue to install SCRs for compliance with state and federal environmental regulations
Option 2—Stop installation of SCRs and replace the coal-fired generation from units 3 and 4 with a CCCT.
Overall Analysis Methodology
The study approach examined the costs and benefits of each option. The company’s share of the nominal generation capacity at units 3 and 4 of 351 MW was assumed to be replaced with a CCCT with the same capacity. Incremental capital investment and fixed operations and maintenance (O&M) were included in
the analysis. In addition, the fuel and variable O&M were forecasted for the duration of the study period
to forecast the total cost of generation, both fixed and variable, for each compliance option.
The 2015 SCR Analysis utilized a 20-year study period over which the costs of both options are calculated. One difference between the 2015 SCR Analysis and the 2013 Coal Study is the inclusion of the return on investment in the net present value (NPV) calculations. In the 2013 Coal Study,
the Science Applications International Corporation (SAIC) capital evaluation approach evaluated the
capital costs of construction without the associated return on investment that is included in the
company’s regulatory revenue requirement determinations.
Option 1 NPV Methodology
The company determined the cost of Option 1 by calculating the revenue requirement of the existing
investment in units 3 and 4, incremental capital additions over the study period, the SCR capital costs
(total SCR construction costs and fixed O&M) over the study period, and decommissioning costs. The additional costs of fuel and O&M related to operating the units over the study period were added to the
revenue requirement of the capital investments.
The revenue requirement associated with the existing investment in units 3 and 4 includes the return on
the existing investment for units 3 and 4, O&M, and fuel costs over the study period. The O&M
information used in the analysis comes from the company’s 10-year budget information from the Jim Bridger Plant forecast through the end of the study period. The company used data from its coal
price forecast over the study period to determine the annual fuel expense including transportation costs.
The company’s coal price forecast is based on long-term contracts for supplying coal to the Jim Bridger
Plant. The incremental capital additions include the cost of the SCRs as well as routine capital
expenditures for maintenance and repairs throughout the study period. Also included as part of the costs of Option 1 are the decommissioning costs for units 3 and 4 that will be required when the units are
retired. The company took the present value of the annual cost stream over the study period to determine
the cost of Option 1. The cost of continuing to install the SCRs for compliance is $1.42 billion over the
study period.
Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis Idaho Power Company
Page 124 2015 Integrated Resource Plan—Appendix C
Option 2 NPV Methodology
The costs of Option 2 is the combination of the costs to shutdown units 3 and 4 and build a CCCT to replace the generation from those shuttered units. The shutdown costs of units 3 and 4 include the
accelerated recovery of the existing investment at units 3 and 4, accelerated recovery of the costs-to-date
of the SCRs (dollars committed including cancelation penalties as of December 31, 2014),
and decommissioning costs. By shutting down units 3 and 4 early, future ongoing capital costs on
units 3 and 4 are avoided. The revenue requirement of the CCCT includes construction costs, fixed O&M, and return on investment over a 20-year period. The cost of the CCCT was based on the
costs identified in the 2015 IRP for this type of resource. The assumption is that the CCCT would be
sized to exactly replace the MW capacity of units 3 and 4. The CCCT in the analysis has an 85 percent
capacity factor with an assumed heat rate of 6,714 Btu/kWh. The natural gas price forecast used in the
analysis is an Idaho Citygate price forecast based on the 2015 IRP. The Idaho Citygate price is a Henry hub gas price with a Sumas hub differential applied plus transportation costs. It is assumed the
CCCT would be sited in a region with access to the Sumas hub natural gas pricing, with additional gas
transportation charges and capacity to a generic Idaho Citygate. The costs of shuttering units 3 and 4 and
replacing that capacity with a CCCT are $2.496 billion over the study period.
Analysis Results
Over the study period, the NPV of Option 1 is $1.420 billion and the NPV of Option 2 is $2.496 billion.
Option 1, continuing to install the SCRs for compliance, is $1.076 billion less than compliance
alternative Option 2.
The company performed additional analyses on the results to determine the main drivers of the
$1.076 billion difference. As shown in the table below, $793 million was due to higher fuel costs in
Option 2, $186 million was due to a higher return on capital investment in Option 2 due to the higher
capital costs, O&M costs were $35 million less than Option 1 as a CCCT would be less O&M intensive
than the Jim Bridger Plant, and capital costs for Option 2 were $132 million higher.
Option 2 Impact of Various Cost Drivers
Impact from fuel costs: $793,308,007
Impact from ROI: 185,890,627
Impact from difference in O&M: (35,319,989)
Impact due to difference in capital costs: 132,407,174
Total $1,076,285,819
Conclusions and Recommendations
Based on the 2015 SCR Analysis, continuing with the installation of the SCRs on units 3 and 4 represents a cost savings of $1.076 billion compared to shuttering units 3 and 4 and replacing that generation with a CCCT resource. The company evaluated the changes in environmental regulations
proposed since the 2013 Coal Study and believes there will be little impact to the normal operation of
units 3 and 4. The SCRs remain the least-cost and least risk option for compliance and the company will
continue the installation of the SCRs on units 3 and 4.
Idaho Power Company Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis
2015 Integrated Resource Plan—Appendix C Page 125
Revenue Requirement Comparison between Jim Bridger
Units 3 and 4 SCR Completion and CCCT Replacement
Revenue Requirement on Existing Investments
Year Existing Investments
2015 $101,017,077
2016 $101,191,683
2017 $102,260,140
2018 $102,958,825
2019 $103,167,948
2020 $94,039,451
2021 $91,247,597
2022 $91,513,087
2023 $94,069,370
2024 $107,116,956
2025 $108,120,849
2026 $109,746,974
2027 $111,413,380
2028 $113,148,724
2029 $114,824,751
2030 $116,577,779
2031 $118,486,952
2032 $120,459,297
2033 $122,496,977
2034 $124,607,408
Total $2,148,465,226

Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis Idaho Power Company
Page 126 2015 Integrated Resource Plan—Appendix C
Revenue Requirement on Incremental Investments
Bridger Capital
Forecast
Life
(years)
Assumed
In-Service 2015 2016 2017 2018 2019
2015 90,802,222 20 12/31/2015 $14,340,755 — — — —
2016 44,787,706 19 12/31/2016 $13,838,158 $7,184,838 — — —
2017 13,508,618 18 12/31/2017 $13,335,560 $6,923,888 $2,204,363 — —
2018 18,268,574 17 12/31/2018 $12,832,963 $6,662,937 $2,121,284 $3,037,499 —
2019 14,439,932 16 12/31/2019 $12,330,366 $6,401,986 $2,038,205 $2,918,537 $2,451,064
2020 9,596,002 15 12/31/2020 $11,827,769 $6,141,035 $1,955,126 $2,799,575 $2,351,156
2021 7,181,971 14 12/31/2021 $11,325,172 $5,880,084 $1,872,047 $2,680,613 $2,251,249
2022 5,935,721 13 12/31/2022 $10,822,575 $5,619,133 $1,788,968 $2,561,650 $2,151,341
2023 7,897,482 12 12/31/2023 $10,319,978 $5,358,183 $1,705,889 $2,442,688 $2,051,434
2024 7,633,488 11 12/31/2024 $9,817,381 $5,097,232 $1,622,810 $2,323,726 $1,951,526
2025 7,648,933 10 12/31/2025 $9,314,784 $4,836,281 $1,539,730 $2,204,764 $1,851,618
2026 7,259,519 9 12/31/2026 $8,812,187 $4,575,330 $1,456,651 $2,085,801 $1,751,711
2027 7,275,029 8 12/31/2027 $8,309,589 $4,314,379 $1,373,572 $1,966,839 $1,651,803
2028 7,542,890 7 12/31/2028 $7,806,992 $4,053,428 $1,290,493 $1,847,877 $1,551,895
2029 7,471,972 6 12/31/2029 $7,304,395 $3,792,477 $1,207,414 $1,728,914 $1,451,988
2030 7,439,668 5 12/31/2030 $6,801,798 $3,531,527 $1,124,335 $1,609,952 $1,352,080
2031 7,397,816 4 12/31/2031 $6,299,201 $3,270,576 $1,041,256 $1,490,990 $1,252,172
2032 7,425,475 3 12/31/2032 $5,796,604 $3,009,625 $958,177 $1,372,028 $1,152,265
2033 7,455,564 2 12/31/2033 $5,294,007 $2,748,674 $875,097 $1,253,065 $1,052,357
2034 7,438,099 1 12/31/2034 $4,791,410 $2,487,723 $792,018 $1,134,103 $952,450
Total $191,321,644 $91,889,335 $26,967,437 $35,458,621 $27,228,109

Bridger Capital Forecast Life (years) Assumed In-Service 2020 2021 2022 2023 2024
2015 90,802,222 20 12/31/2015 — — — — —
2016 44,787,706 19 12/31/2016 — — — — —
2017 13,508,618 18 12/31/2017 — — — — —
2018 18,268,574 17 12/31/2018 — — — — —
2019 14,439,932 16 12/31/2019 — — — — —
2020 9,596,002 15 12/31/2020 $1,666,615 — — — —
2021 7,181,971 14 12/31/2021 $1,595,796 $1,279,658 — — —
2022 5,935,721 13 12/31/2022 $1,524,977 $1,222,868 $1,088,414 — —
2023 7,897,482 12 12/31/2023 $1,454,157 $1,166,079 $1,037,869 $1,495,959 —
2024 7,633,488 11 12/31/2024 $1,383,338 $1,109,289 $987,323 $1,423,104 $1,500,581
2025 7,648,933 10 12/31/2025 $1,312,518 $1,052,500 $936,777 $1,350,249 $1,423,759
2026 7,259,519 9 12/31/2026 $1,241,699 $995,710 $886,232 $1,277,393 $1,346,938
2027 7,275,029 8 12/31/2027 $1,170,879 $938,920 $835,686 $1,204,538 $1,270,116
2028 7,542,890 7 12/31/2028 $1,100,060 $882,131 $785,141 $1,131,683 $1,193,294
2029 7,471,972 6 12/31/2029 $1,029,240 $825,341 $734,595 $1,058,827 $1,116,473
2030 7,439,668 5 12/31/2030 $958,421 $768,551 $684,049 $985,972 $1,039,651
2031 7,397,816 4 12/31/2031 $887,602 $711,762 $633,504 $913,117 $962,829
2032 7,425,475 3 12/31/2032 $816,782 $654,972 $582,958 $840,262 $886,008
2033 7,455,564 2 12/31/2033 $745,963 $598,182 $532,412 $767,406 $809,186
2034 7,438,099 1 12/31/2034 $675,143 $541,393 $481,867 $694,551 $732,364
Total $12,747,356 $10,206,828 $13,143,061 $12,281,200 $11,882,675
Idaho Power Company Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis
2015 Integrated Resource Plan—Appendix C Page 127
Bridger Capital Forecast Life (years) Assumed In-Service 2025 2026 2027 2028 2029
2015 90,802,222 20 12/31/2015 — — — — —
2016 44,787,706 19 12/31/2016 — — — — —
2017 13,508,618 18 12/31/2017 — — — — —
2018 18,268,574 17 12/31/2018 — — — — —
2019 14,439,932 16 12/31/2019 — — — — —
2020 9,596,002 15 12/31/2020 — — — — —
2021 7,181,971 14 12/31/2021 — — — — —
2022 5,935,721 13 12/31/2022 — — — — —
2023 7,897,482 12 12/31/2023 — — — — —
2024 7,633,488 11 12/31/2024 — — — — —
2025 7,648,933 10 12/31/2025 $1,569,304 — — — —
2026 7,259,519 9 12/31/2026 $1,484,629 $1,565,606 — — —
2027 7,275,029 8 12/31/2027 $1,399,955 $1,476,313 $1,664,400 — —
2028 7,542,890 7 12/31/2028 $1,315,280 $1,387,020 $1,563,731 $1,852,921 —
2029 7,471,972 6 12/31/2029 $1,230,605 $1,297,726 $1,463,061 $1,733,634 $2,003,557
2030 7,439,668 5 12/31/2030 $1,145,930 $1,208,433 $1,362,392 $1,614,347 $1,865,697
2031 7,397,816 4 12/31/2031 $1,061,255 $1,119,140 $1,261,722 $1,495,060 $1,727,838
2032 7,425,475 3 12/31/2032 $976,580 $1,029,846 $1,161,053 $1,375,773 $1,589,978
2033 7,455,564 2 12/31/2033 $891,906 $940,553 $1,060,383 $1,256,486 $1,452,118
2034 7,438,099 1 12/31/2034 $807,231 $851,260 $959,713 $1,137,199 $1,314,259
Total $11,882,675 $10,875,898 $10,496,455 $10,465,423 $9,953,447

Bridger Capital Forecast Life (years) Assumed In-Service 2030 2031 2032 2033 2034
2015 90,802,222 20 12/31/2015 — — — — —
2016 44,787,706 19 12/31/2016 — — — — —
2017 13,508,618 18 12/31/2017 — — — — —
2018 18,268,574 17 12/31/2018 — — — — —
2019 14,439,932 16 12/31/2019 — — — — —
2020 9,596,002 15 12/31/2020 — — — — —
2021 7,181,971 14 12/31/2021 — — — — —
2022 5,935,721 13 12/31/2022 — — — — —
2023 7,897,482 12 12/31/2023 — — — — —
2024 7,633,488 11 12/31/2024 — — — — —
2025 7,648,933 10 12/31/2025 — — — — —
2026 7,259,519 9 12/31/2026 — — — — —
2027 7,275,029 8 12/31/2027 — — — — —
2028 7,542,890 7 12/31/2028 — — — — —
2029 7,471,972 6 12/31/2029 — — — — —
2030 7,439,668 5 12/31/2030 $2,229,158 — — — —
2031 7,397,816 4 12/31/2031 $2,064,441 $2,566,035 — — —
2032 7,425,475 3 12/31/2032 $1,899,725 $2,361,297 $3,160,168 — —
2033 7,455,564 2 12/31/2033 $1,735,008 $2,156,560 $2,886,164 $4,346,789 —
2034 7,438,099 1 12/31/2034 $1,570,292 $1,951,823 $2,612,160 $3,934,118 $7,849,803
Total $9,498,625 $9,035,714 $8,658,492 $8,280,906 $7,849,803

Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis Idaho Power Company
Page 128 2015 Integrated Resource Plan—Appendix C
Revenue Requirement on Decommissioning Costs
Decommissioning Costs (Estimated in 2034 dollars)
2034 Costs $52,244,513
Present Value $29,794,316
Annual Payment $1,241,717

Total Payments—Comparison between Option 1 & 2
Option 1 Option 2
Year Continue w/SCR
Total Payments
Accelerated Shutdown*
Costs of
Replacement CCCT
Total Annual Costs Difference between Option 1 & 2
2015 $116,599,549 $335,842,318 $169,233,797 $505,076,115 $388,476,567
2016 $123,456,396 $351,737,422 $159,080,882 $510,818,304 $387,361,908
2017 $125,965,668 $158,051,633 $158,051,633 $32,085,964
2018 $128,855,226 $164,658,910 $164,658,910 $35,803,683
2019 $130,549,824 $170,473,692 $170,473,692 $39,923,868
2020 $122,022,445 $172,507,122 $172,507,122 $50,484,678
2021 $119,373,933 $174,789,729 $174,789,729 $55,415,797
2022 $119,534,731 $175,912,781 $175,912,781 $56,378,050
2023 $122,343,322 $179,087,087 $179,087,087 $56,743,766
2024 $135,574,982 $181,551,652 $181,551,652 $45,976,670
2025 $136,754,850 $183,671,759 $183,671,759 $46,916,909
2026 $138,468,578 $181,060,725 $181,060,725 $42,592,147
2027 $140,232,087 $181,088,595 $181,088,595 $40,856,508
2028 $142,152,387 $183,931,004 $183,931,004 $41,778,617
2029 $144,044,717 $188,184,330 $188,184,330 $44,139,613
2030 $146,101,790 $195,077,058 $195,077,058 $48,975,268
2031 $148,487,168 $201,099,893 $201,099,893 $52,612,724
2032 $151,325,114 $203,445,436 $203,445,436 $52,120,322
2033 $155,141,012 $209,308,283 $209,308,283 $54,167,271
2034 $162,120,005 $58,279,478** $58,279,478 $(103,840,527)
NPV $1,419,569,231 $2,495,855,049 $1,076,285,818
*Bridger SCR 3 and 4 Stacked PWorth—accelerated
**Residual value (Book value) included in the final year: (163,567,666)

Idaho Power Company Fuel Data
2015 Integrated Resource Plan—Appendix C Page 129
FUEL PRICE FORECAST
Natural Gas and Coal Price Forecast (nominal $/MMBtu)
Year Generic Coal Nuclear Planning Case High Case Low Case
2015 $5.10 $5.32 $4.74 $1.47 $0.51
2016 $4.70 $5.02 $4.24 $1.52 $0.52
2017 $4.76 $5.26 $4.02 $1.55 $0.53
2018 $5.25 $5.56 $4.27 $1.58 $0.54
2019 $5.69 $6.22 $5.02 $1.61 $0.56
2020 $5.91 $6.94 $5.85 $1.64 $0.57
2021 $6.14 $7.17 $5.85 $1.69 $0.58
2022 $6.30 $7.54 $5.99 $1.74 $0.59
2023 $6.58 $8.04 $6.27 $1.78 $0.61
2024 $6.82 $8.49 $6.21 $1.83 $0.62
2025 $7.04 $9.13 $6.24 $1.87 $0.63
2026 $6.99 $9.38 $5.57 $1.91 $0.65
2027 $7.09 $9.73 $5.17 $1.98 $0.66
2028 $7.35 $10.24 $5.38 $2.00 $0.68
2029 $7.69 $10.64 $5.60 $2.07 $0.69
2030 $8.18 $11.18 $5.77 $2.12 $0.71
2031 $8.62 $11.62 $6.10 $2.16 $0.72
2032 $8.85 $11.78 $6.09 $2.21 $0.74
2033 $9.28 $12.24 $6.33 $2.27 $0.75
2034 $10.09 $13.21 $6.94 $2.32 $0.77

2015 IRP Fuel Price Forecast

$/M
M
B
t
u

(
n
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i
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l
)
Forecast Period
Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis Idaho Power Company
Page 130 2015 Integrated Resource Plan—Appendix C
Historical EIA Henry Hub Spot Price Forecasts

$0
$1
$2
$3
$4
$5
$6
$7
$8
$9
$10
$11
$12
$13
$14
$15
2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034
Na
t
u
r
a
l

G
a
s

P
r
i
c
e

(
n
o
m
i
n
a
l

$
/
M
M
B
t
u
)
Forecast Period
2010 EIA Forecast
2011 EIA Forecast
2012 EIA Forecast (2013 IRP)
2013 EIA Forecast
2014 EIA Forecast (2015 IRP)
*all values taken from EIA Annual Energy Outlook reports:
http://www.eia.gov/oiaf/aeo/tablebrowser/#release=AEO2013&subject=0-AEO2013&table=13-AEO2013&region=0-0&cases=ref2013-d102312a
Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 131
EXISTING RESOURCE DATA
Hydroelectric and Thermal Plant Data
Nameplate
Hydroelectric Power Plans kVA kW Normal Rating kW Emergency Rating kW
American Falls ................................102,600 92,340 92,340 106,190
Bliss ................................................................86,250 75,000 75,000 84,860
Brownlee ................................................................650,444 585,400 585,400 678,040
Cascade ................................................................13,800 12,420 12,420 14,280
C.J. Strike ................................................................90,000 82,800 82,800 95,420
Clear Lake ................................................................3,125 2,500 2,420 2,430
Hells Canyon ................................435,000 391,500 391,500 449,580
Lower Salmon ................................70,000 60,000 60,000 69,140
Malad–Lower ................................15,500 13,500 13,500 13,500
Malad–Upper ................................9,650 8,270 8,270 8,400
Milner ................................................................62,890 59,448 59,448 61,880
Oxbow ................................................................211,112 190,000 190,000 218,520
Shoshone Falls ................................14,900 12,500 12,500 12,500
Swan Falls ................................................................28,600 27,170 24,170 24,170
Thousand Springs ................................11,000 8,800 6,3802 6,380
Twin Falls ................................................................56,175 52,897 52,561 54,170
Upper Salmon “A” ................................18,000 18,000 18,000 18,000
Upper Salmon “B” ................................18,000 16,500 16,500 16,560
Total Hydro ................................................................ 1,897,046 1,709,045

Generator Nameplate Rating Net Dependable Capability (NDC)
Thermal, Natural Gas, and Diesel Power Plans Gross kVA Gross kW kW Summer kW Winter kW
Bridger (Idaho Power share) .................................................. 811,053 770,501 707,667 707,667
Boardman (Idaho Power share) ............................................. 67,600 64,200 57,550 58,050
Valmy (Idaho Power share) ................................................... 315,000 283,500 260,000 260,000
Total Thermal ....................................................................... 1,193,653 1,118,201
Bennett Mountain .................................................................. 192,000 172,800 164,159
Evander Andrews Unit #1 ...................................................... 199,000 179,100 170,955
Evander Andrews Unit #2 ...................................................... 51,000 45,900 45,405
Evander Andrews Unit #3 ...................................................... 51,000 45,900 45,066
Langley Gulch CT .................................................................. 220,000 187,000 176,880
Langley Gulch ST .................................................................. 154,650 131,452 122,765
Total Natural Gas ................................................................. 867,650 762,152
Salmon Diesel ....................................................................... 6,880 5,000 5,500
Total IPC Generation ........................................................... 3,965,229 3,594,398
is no nameplate kW rating.
2 The two smaller units, 1 and 2, have nameplate ratings of 1.25 MVA and 1 MW and are not in service due to reduced flows from the springs and penstock integrity.
3 The Swan Falls units have been limited to 24,170 kW as a result of vibration issues.
4 Normal Rating is the normal kW output of the facility with all units on-line. This rating includes all equipment limitations and may be lower than the nameplate rating. To operate at the Normal Rating, appropriate water conditions must exist and the FERC license requirements permit.
5 Emergency Rating is the maximum kW output of the facility with all units on-line. The Emergency Rating is based on manufacturer guidelines, ANSI standards, and limited by auxiliary equipment ratings. To operate at the Emergency Rating, appropriate water conditions must exist and the FERC license requirements permit.
6 Ratings for coal-fired generators are provided by Idaho Power's thermal partners who operate these plants.
7 NDC is defined in the NERC Generating Availability Data System (GADS) as Gross Dependable Capacity (GDC) less the unit capacity utilized for that unit's station service or auxiliaries. GDC is the Gross Maximum Capacity (GMC) modified for seasonal limitations over a specified period of time. The GDC and Maximum Dependable Capacity (MDC) used in previous GADS reports are the same in intent and purpose. GMC is the maximum capacity a unit can sustain over a specified period of time when not restricted by
Existing Resource Data Idaho Power Company
Page 132 2015 Integrated Resource Plan—Appendix C
Qualifying Facility Data (PURPA)
Cogeneration and Small Power Production Projects
Status as of May 26, 2015.
Contract Contract
Project MW On-line Date End Date Project MW On-line Date End Date
Hydro Projects
Arena Drop 0.45 Sep-2010 Sep-2030 Little Wood Rvr Res 2.85 Feb-1985 Feb-2020
Barber Dam 3.70 Apr-1989 Apr-2024 Littlewood / Arkoosh 0.87 Aug-1986 Aug-2021
Birch Creek 0.05 Nov-1984 Nov-2019 Low Line Canal 7.97 May-1985 May-2020
Black Canyon #3 0.14 Apr-1984 Apr-2019 Low Line Midway Hydro 2.50 Aug-2007 Aug-2027
Black Canyon Bliss Hydro 0.03 Nov-2014 Estimated Lowline #2 2.79 Apr-1988 Apr-2023
Blind Canyon 1.63 Dec-2014 Dec-2034 Magic Reservoir 9.07 Jun-1989 Jun-2024
Box Canyon 0.36 Feb-1984 Feb-2019 Malad River 0.62 May-1984 May-2019
Briggs Creek 0.60 Oct-1985 Oct-2020 Marco Ranches 1.20 Aug-1985 Aug-2020
Bypass 9.96 Jun-1988 Jun-2023 Mile 28 1.50 Jun-1994 Jun-2029
Canyon Springs 0.13 Oct-1984 Oct-2040 Mill Creek Hydroelectric 0.80 Oct-2011 Jun-2017
Cedar Draw 1.55 Jun-1984 Jun-2019 Mitchell Butte 2.09 May-1989 Dec-2033
Clark Canyon Hydroelectric 7.55 Jun-2017 Estimated Mora Drop Small Hydro Fac 1.85 Sep-2006 Sep-2026
Clear Springs Trout 0.52 Nov-1983 Nov-2018 Mud Creek/S&S 0.52 Feb-1982 Jan-2017
Crystal Springs 2.44 Apr-1986 Apr-2021 Mud Creek/White 0.21 Jan-1986 Jan-2021
Curry Cattle Company 0.22 Jun-1983 Jun-2018 Owyhee Dam Cspp 5.00 Aug-1985 May-2033
Dietrich Drop 4.50 Aug-1988 Aug-2023 Pigeon Cove 1.89 Oct-1984 Oct-2019
Eightmile Hydro Project 0.36 Oct-2014 Oct-2034 Pristine Springs #1 2005 0.13 May-2005 May-2015
Elk Creek 2.00 May-1986 May-2021 Pristine Springs #3 2005 0.20 May-2005 May-2015
Falls River 9.10 Aug-1993 Aug-2028 Reynolds Irrigation 0.26 May-1986 May-2021
Fargo Drop Hydroelectric 1.27 Apr-2013 Apr-2033 Rock Creek #1 2.05 Sep-1983 Sep-2018
Faulkner Ranch 0.87 Aug-1987 Aug-2022 Rock Creek #2 1.90 Apr-1989 Apr-2024
Fisheries Dev. 0.26 Jul-1990 Jul-2040 Sagebrush 0.43 Sep-1985 Sep-2020
Geo-Bon #2 0.93 Nov-1986 Nov-2021 Sahko Hydro 0.50 Feb-2011 Feb-2021
Hailey Cspp 0.06 Jun-1985 Jun-2020 Schaffner 0.53 Aug-1986 Aug-2021
Hazelton A 8.10 Mar-2011 Mar-2026 Shingle Creek 0.22 Aug-1983 Aug-2017
Hazelton B 7.60 May-1993 May-2028 Shoshone #2 0.58 May-1996 May-2031
Head of U Canal Project 1.28 May-2015 Estimated Shoshone Cspp 0.37 Jun-1982 Feb-2017
Horseshoe Bend Hydro 9.50 Sep-1995 Sep-2030 Snake River Pottery 0.07 Nov-1984 Nov-2019
Jim Knight 0.34 Jun-1985 Jun-2020 Snedigar 0.54 Jan-1985 Jan-2020
Kasel & Witherspoon 0.90 Mar-1984 Mar-2019 Tiber Dam 7.50 Jun-2004 Jun-2024
Koyle Small Hydro 1.25 Apr-1984 Apr-2019 Trout-Co 0.24 Dec-1986 Dec-2021
Lateral # 10 2.06 May-1985 May-2020 Tunnel #1 7.00 Jun-1993 Feb-2035
Lemoyne 0.08 Jun-1985 Jun-2020 White Water Ranch 0.16 Aug-1985 Aug-2020
Little Wood River Ranch II 1.25 Jun-2015 Estimated Wilson Lake Hydro 8.40 May-1993 May-2028
Total Hydro Nameplate Rating 153.81 MW
Thermal Projects
Magic Valley Natural Gas Nov-1996 Nov-2016 TASCO—Nampa Natural Gas 2.00 Sep-2003
Simplot Pocatello Cogen Mar-2013 Feb-2016 TASCO—Twin Falls Natural Gas 3.00 Aug-2001
Total Thermal Nameplate Rating 30.90 MW

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 133
Contract Contract
Project MW On-line Date End Date Project MW On-line Date End Date
Biomass Projects
B6 Anaerobic Digester 2.28 Aug-2010 Aug-2020 Fighting Creek Landfill 3.06 Apr-2014 Apr-2029
Bannock County Landfill 3.20 May-2014 May-2034 Hidden Hollow Landfill Gas 3.20 Jan-2007 Jan-2027
2.25 May-2010 May-2020 Pocatello Waste 0.46 Dec-1985 Dec-2020
Big Sky West Dairy Digester 1.50 Jan-2009 Jan-2029 Rock Creek Dairy 4.00 Aug-2012 Aug-2027
Double A Digester Project 4.50 Jan-2012 Jan-2032 Tamarack CSPP 5.00 Jun-1983 Jun-2018
Total Biomass Nameplate Rating 29.45 MW
Solar Projects

American Falls Solar II, LLC 20.00 Dec-2016 Estimated Open Range Solar Center, LLC 10.00 Dec-2016 Estimated
American Falls Solar, LLC 40.00 Jan-2016 Estimated Orchard Ranch Solar, LLC 20.00 Dec-2016 Estimated
Boise City Solar, LLC 80.00 Sep-2016 Estimated Pocatello Solar 1, LLC 20.00 Dec-2016 Estimated
Grand View PV Solar Two 10.00 Dec-2016 Estimated Railroad Solar Center, LLC 10.00 Dec-2016 Estimated
Grove Solar Center, LLC 10.00 Dec-2016 Estimated Simco Solar, LLC 20.00 Dec-2016 Estimated
Hyline Solar Center, LLC 20.00 Dec-2016 Estimated Thunderegg Solar Center, LLC 10.00 Dec-2016 Estimated
Mountain Home Solar, LLC 20.00 Dec-2016 Estimated Vale Air Solar Center, LLC 10.00 Dec-2016 Estimated
Murphy Flat Power, LLC 20.00 Dec-2016 Estimated
Total Solar Nameplate Rating 320 MW
Wind Projects
Bennett Creek Wind Farm 21.00 Dec-2008 Dec-2028 Mainline Windfarm 23.00 Dec-2012 Dec-2032
Benson Creek Windfarm 10.00 Dec-2016 Estimated Milner Dam Wind 19.92 Feb-2011 Feb-2031
Burley Butte Wind Park 21.30 Feb-2011 Feb-2031 Oregon Trail Wind Park 13.50 Jan-2011 Jan-2031
Camp Reed Wind Park 22.50 Dec-2010 Dec-2030 Payne's Ferry Wind Park 21.00 Dec-2010 Dec-2030
Cassia Wind Farm LLC 10.50 Mar-2009 Mar-2029 Pilgrim Stage Station Wind Park 10.50 Jan-2011 Jan-2031
Cold Springs Windfarm 23.00 Dec-2012 Dec-2032 Prospector Windfarm 10.00 Dec-2016 Estimated
Desert Meadow Windfarm 23.00 Dec-2012 Dec-2032 Rockland Wind Farm 80.00 Dec-2011 Dec-2036
Durbin Creek Windfarm 10.00 Dec-2016 Estimated Ryegrass Windfarm 23.00 Dec-2012 Dec-2032
Fossil Gulch Wind 10.50 Sep-2005 Sep-2025 Salmon Falls Wind 22.00 Apr-2011 Apr-2031
Golden Valley Wind Park 12.00 Feb-2011 Feb-2031 Sawtooth Wind Project 22.00 Nov-2011 Nov-2031
Hammett Hill Windfarm 23.00 Dec-2012 Dec-2032 Thousand Springs Wind Park 12.00 Jan-2011 Jan-2031
High Mesa Wind Project 40.00 Dec-2012 Dec-2032 Tuana Gulch Wind Park 10.50 Jan-2011 Jan-2031
Horseshoe Bend Wind 9.00 Feb-2006 Feb-2026 Tuana Springs Expansion 35.70 May-2010 May-2030
Hot Springs Wind Farm 21.00 Dec-2008 Dec-2028 Two Ponds Windfarm 23.00 Dec-2012 Dec-2032
Jett Creek Windfarm 10.00 Dec-2016 Estimated Willow Spring Windfarm 10.00 Dec-2016 Estimated
Lime Wind Energy 3.00 Dec-2011 Dec-2031 Yahoo Creek Wind Park 21.00 Dec-2010 Dec-2030
Total Wind Nameplate Rating 626.92 MW
Total Nameplate Rating 1,161.80 MW
The above is a summary of the Nameplate rating for the CSPP projects under contract with Idaho Power as of May 26, 2015. In the case of CSPP projects, Nameplate rating of the actual generation units is not an accurate or reasonable estimate of the actual energy these projects will deliver to Idaho Power. Historical generation information, resource specific industry standard capacity factors, and other known and measurable operating characteristics are accounted for in determining a reasonable estimate of the energy these projects will produce.

Existing Resource Data Idaho Power Company
Page 134 2015 Integrated Resource Plan—Appendix C
Power Purchase Agreement Data
Idaho Power Company Power Purchase Agreements Status as of April 1, 2015
Contract
Wind projects
Elkhorn Wind Project ................................................................101 December 2007 December 2027
Total wind nameplate MW rating ................................................................ 101
Geothermal Projects
Raft River Unit 1 ................................................................13 April 2008 April 2033
Neal Hot Springs ................................................................22 November 2012 November 2037
Total geothermal nameplate MW rating ................................ 35
Total nameplate MW rating ................................................................ 136
1. Above is a summary of the nameplate ratings for the Power Purchase Agreements under contract with Idaho Power. Nameplate ratings of the actual generation units are not an accurate or reasonable estimate of the actual energy these projects will deliver to Idaho Power. Historical generation information, resource-specific industry standard capacity factors, and other known and measurable operating characteristics are accounted for in determining a reasonable estimate of the energy the projects will produce.
2. Not included in the above table is the energy exchange agreement between Idaho Power and the Clatskanie PUD. Under the exchange, Idaho Power receives energy from the 18-MW power plant at Arrowrock Dam on the Boise River and returns to Clatskanie PUD energy of an equivalent
value delivered seasonally. The agreement began in January 2010 and extends through 2015. Idaho Power retains the right to renew the agreement through 2025.

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 135
Hydro Modeling Results (PDR580)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015 aMW
Brownlee HCC* 319.5 359.7 341.3 433.4 409.9 397.5 247.5 164.8 212.9 193.7 152.6 253.6 290.5
Oxbow HCC 131.7 155.5 155.1 188.7 168.0 161.7 105.0 75.3 97.5 89.0 69.3 106.8 125.3
Hells Canyon HCC 259.2 308.6 313.1 386.6 346.5 326.9 208.1 148.1 191.3 175.5 138.1 211.7 251.1
1000 Springs ROR**24.4 25.8 26.0 58.3 83.0 89.5 83.9 64.8 43.1 16.1 - 17.4 44.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.5 50.4 44.0 54.2 48.2 42.0 35.3 28.3 37.3 40.0 38.4 45.8 42.8
C .J. Strike ROR 64.7 66.1 58.9 70.6 60.8 52.2 36.9 31.4 44.6 51.0 50.7 59.9 54.0
Cascade ROR 1.5 1.5 2.8 5.9 5.5 11.7 10.3 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.9 35.5 29.3 38.4 34.2 28.3 23.0 16.1 23.6 26.0 24.3 31.5 28.8
Milner ROR 41.5 42.1 26.3 42.5 34.3 15.4 6.2 - - - 4.9 30.8 20.3
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 11.0
Swan Falls ROR 20.9 21.3 19.0 22.6 19.9 17.1 12.9 11.0 15.0 16.9 16.8 19.4 17.7
Twin Falls ROR 40.8 41.8 27.9 45.8 34.7 20.1 10.5 - - 6.6 9.1 31.6 22.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 19.1 19.1 17.6 18.1 14.1 8.9 14.5 16.1 14.9 19.2 16.7
Upper Salmon 3&4 ROR 17.7 17.7 17.6 17.7 17.7 16.2 13.2 8.9 13.6 15.0 13.9 17.7 15.6
HCC Total 710.4 823.8 809.5 1,008.7 924.3 886.1 560.6 388.2 501.7 458.2 360.0 572.1 667.0
ROR Total 353.1 360.4 310.6 414.6 396.6 349.8 285.2 217.2 235.8 228.4 212.9 313.1 306.5
Total 1,063.5 1,184.2 1,120.1 1,423.3 1,320.9 1,235.9 845.8 605.4 737.5 686.6 572.9 885.2 973.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016 aMW
Brownlee HCC* 319.9 361.6 342.8 440.7 419.2 406.5 247.9 164.5 212.8 193.5 152.7 254.7 293.1
Oxbow HCC 131.9 156.3 155.7 191.7 171.7 165.2 105.2 75.2 97.5 88.9 69.4 107.3 126.3
Hells Canyon HCC 259.5 310.1 314.4 392.7 353.8 333.8 208.5 147.8 191.4 175.4 138.2 212.6 253.2
1000 Springs ROR**24.8 26.5 26.8 60.7 84.5 90.9 83.9 64.9 42.8 16.1 - 19.3 45.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.4 50.5 44.2 55.0 49.1 42.3 35.2 28.2 37.2 40.0 38.0 47.3 43.0
C .J. Strike ROR 64.6 66.1 59.6 70.7 63.4 53.4 36.7 31.3 44.5 51.0 50.6 60.7 54.4
Cascade ROR 1.5 1.5 2.8 5.9 5.5 11.7 10.3 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.9 35.7 29.7 38.9 35.0 28.9 23.0 16.0 23.5 25.9 24.3 32.5 29.0
Milner ROR 42.0 43.0 26.9 42.5 36.7 17.3 6.2 - - - 4.9 34.6 21.2
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 11.0
Swan Falls ROR 20.9 21.3 19.3 22.8 20.4 17.5 12.9 11.0 14.9 16.8 16.7 19.6 17.8
Twin Falls ROR 41.7 42.1 28.0 45.8 36.7 21.3 10.5 - - 6.6 9.1 35.4 23.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 19.2 19.1 17.6 18.6 14.0 8.9 14.4 16.1 14.8 19.2 16.7
Upper Salmon 3&4 ROR 17.7 17.7 17.7 17.7 17.7 16.2 13.2 8.8 13.5 15.0 13.9 17.7 15.6
HCC Total 711.3 828.0 812.9 1,025.1 944.7 905.5 561.6 387.5 501.6 457.8 360.3 574.6 672.6
ROR Total 354.7 362.6 313.9 418.6 407.3 357.3 284.8 216.9 235.0 228.2 212.2 326.1 309.8
Total 1,066.0 1,190.6 1,126.8 1,443.7 1,351.9 1,262.8 846.4 604.4 736.6 686.0 572.5 900.7 982.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 136 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017 aMW
Brownlee HCC* 319.1 365.2 343.4 446.8 429.4 418.8 248.5 164.6 210.7 194.5 152.6 253.7 295.6
Oxbow HCC 131.6 157.8 156.0 194.3 175.8 170.1 105.4 75.2 96.3 89.1 69.2 106.9 127.3
Hells Canyon HCC 258.9 313.1 314.9 397.8 361.8 343.3 209.0 148.0 189.1 175.7 138.0 211.8 255.1
1000 Springs ROR**25.1 26.6 27.1 61.1 85.8 93.3 84.0 65.0 43.1 16.6 - 20.9 45.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.2 50.6 44.2 55.4 50.2 43.6 35.4 28.3 37.2 40.0 38.1 48.2 43.4
C .J. Strike ROR 64.8 66.0 59.4 70.7 65.1 53.7 36.8 31.5 44.5 51.1 50.1 61.7 54.6
Cascade ROR 1.5 1.5 2.8 5.9 5.5 11.7 10.3 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 35.0 35.4 29.6 38.9 35.9 29.3 23.0 16.1 23.4 26.0 23.9 33.0 29.1
Milner ROR 41.5 42.3 27.8 42.9 39.0 20.9 6.2 - - - 3.8 34.8 21.6
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 11.0
Swan Falls ROR 20.9 21.3 19.3 22.7 21.1 17.5 12.9 11.0 14.9 16.8 16.4 19.9 17.9
Twin Falls ROR 41.5 41.6 29.1 45.8 38.7 23.8 10.5 - - 6.6 8.5 35.1 23.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 19.2 19.1 17.6 19.0 14.0 8.9 14.3 16.1 14.5 19.2 16.7
Upper Salmon 3&4 ROR 17.7 17.7 17.7 17.7 17.7 16.2 13.2 8.8 13.4 15.0 13.6 17.7 15.5
HCC Total 709.6 836.1 814.3 1,038.9 967.0 932.2 562.9 387.8 496.1 459.3 359.8 572.4 678.0
ROR Total 354.4 361.2 315.9 419.7 417.3 368.2 285.2 217.4 234.9 228.9 208.8 330.3 311.9
Total 1,064.0 1,197.3 1,130.2 1,458.6 1,384.3 1,300.4 848.1 605.2 731.0 688.2 568.6 902.7 989.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018 aMW
Brownlee HCC* 321.3 364.6 343.3 444.7 432.7 419.1 249.0 164.3 209.5 194.4 153.1 252.6 295.7
Oxbow HCC 132.5 157.5 155.9 193.4 176.8 170.2 105.6 75.1 95.7 88.9 69.4 106.4 127.3
Hells Canyon HCC 260.5 312.6 314.8 396.0 364.4 343.5 209.4 147.7 187.8 175.5 138.3 210.9 255.1
1000 Springs ROR**25.7 28.4 27.0 61.3 86.8 95.1 84.0 65.1 43.1 17.8 - 20.9 46.3
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.5 51.1 43.7 55.4 50.9 44.7 35.3 28.2 37.0 40.0 38.0 47.3 43.4
C .J. Strike ROR 65.4 66.4 58.9 70.7 66.1 54.6 36.7 31.4 44.3 51.0 50.1 61.3 54.7
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 35.1 36.2 29.2 38.9 36.6 30.2 22.9 16.0 23.3 25.9 23.8 32.7 29.2
Milner ROR 41.5 45.0 26.7 44.9 40.9 24.5 6.2 - - - 3.6 34.3 22.3
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 11.0
Swan Falls ROR 20.9 21.4 19.1 22.7 21.3 17.8 12.8 11.0 14.9 16.8 16.4 19.8 17.9
Twin Falls ROR 41.6 43.8 28.3 47.4 40.5 26.9 10.5 - - 6.6 8.5 34.7 24.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 19.1 19.1 17.5 19.2 14.0 8.8 14.2 16.0 14.4 19.2 16.6
Upper Salmon 3&4 ROR 17.7 17.7 17.5 17.7 17.7 16.2 13.2 8.8 13.3 14.9 13.5 17.7 15.5
HCC Total 714.3 834.7 814.0 1,034.1 973.9 932.8 564.0 387.1 493.0 458.8 360.8 569.9 678.1
ROR Total 356.1 369.8 312.0 423.5 424.3 380.4 284.7 217.1 234.2 229.8 208.2 327.7 314.0
Total 1,070.4 1,204.5 1,126.0 1,457.6 1,398.1 1,313.2 848.7 604.2 727.2 688.6 569.0 897.6 992.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 137
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019 aMW
Brownlee HCC* 320.0 363.3 344.2 441.7 437.9 419.7 249.6 164.8 207.5 195.1 153.1 250.3 295.6
Oxbow HCC 132.0 157.0 156.3 192.2 177.8 170.4 105.9 75.3 94.5 89.0 69.3 105.4 127.1
Hells Canyon HCC 259.6 311.5 315.6 393.5 368.5 344.0 209.9 148.1 185.6 175.5 138.1 208.9 254.9
1000 Springs ROR**25.9 28.4 27.2 61.0 87.9 95.5 84.1 65.1 43.1 18.2 5.2 18.1 46.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.7 51.4 42.4 54.5 51.5 45.5 35.5 28.4 37.1 40.1 37.2 46.1 43.3
C .J. Strike ROR 65.8 67.4 57.6 70.1 67.0 55.2 36.8 31.5 44.3 51.1 48.8 58.4 54.5
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 35.3 36.6 28.2 38.9 37.4 31.7 23.0 16.1 23.3 25.9 23.4 30.5 29.2
Milner ROR 41.7 44.9 22.6 43.7 42.7 27.2 6.2 - - - - 27.8 21.4
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 21.0 21.5 18.7 22.5 21.6 18.0 12.9 11.1 14.9 16.9 16.1 19.0 17.9
Twin Falls ROR 41.8 43.7 24.7 46.7 41.9 28.9 10.5 - - 6.6 6.0 28.9 23.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 18.3 19.1 17.5 19.2 14.1 8.9 14.2 16.1 14.1 19.2 16.6
Upper Salmon 3&4 ROR 17.7 17.7 16.9 17.7 17.7 16.2 13.2 8.8 13.3 15.0 13.3 17.7 15.4
HCC Total 711.6 831.8 816.1 1,027.4 984.2 934.1 565.4 388.2 487.6 459.6 360.5 564.6 677.6
ROR Total 357.6 371.4 299.1 419.6 431.2 388.6 285.4 217.7 234.3 230.7 201.7 305.5 311.9
Total 1,069.2 1,203.2 1,115.2 1,447.0 1,415.4 1,322.7 850.8 605.9 721.9 690.3 562.2 870.1 989.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020 aMW
Brownlee HCC* 318.8 360.6 343.8 440.8 436.3 418.9 249.0 164.1 205.9 195.3 153.5 249.2 294.7
Oxbow HCC 131.5 155.8 156.2 191.8 177.4 170.1 105.6 75.0 93.7 89.0 69.4 104.9 126.7
Hells Canyon HCC 258.6 309.3 315.3 392.8 367.2 343.3 209.4 147.5 184.0 175.5 138.3 208.0 254.1
1000 Springs ROR**25.7 27.1 26.9 60.7 87.7 95.1 84.1 65.1 42.9 18.5 5.2 16.9 46.3
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.4 51.0 42.2 54.3 51.3 45.2 35.4 28.2 36.8 39.9 37.0 45.2 43.0
C .J. Strike ROR 64.7 65.9 56.8 69.8 66.7 54.6 36.6 31.3 44.0 50.9 48.6 57.1 53.9
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 35.1 35.3 27.8 38.9 37.2 31.2 22.9 15.9 23.0 25.8 23.2 29.7 28.8
Milner ROR 41.4 43.3 22.1 43.4 42.3 27.1 6.2 - - - - 25.7 21.0
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 11.3 12.0 11.0
Swan Falls ROR 20.9 21.3 18.5 22.4 21.5 17.8 12.9 11.0 14.8 16.8 16.0 18.6 17.7
Twin Falls ROR 41.5 43.3 24.3 46.4 41.6 28.9 10.5 - - 6.6 7.4 27.1 23.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 18.0 19.1 17.5 19.2 14.0 8.8 14.0 16.0 14.0 19.1 16.5
Upper Salmon 3&4 ROR 17.7 17.7 16.6 17.7 17.7 16.2 13.2 8.7 13.2 14.9 13.1 17.6 15.4
HCC Total 708.9 825.7 815.3 1,025.4 980.9 932.3 564.0 386.6 483.5 459.8 361.2 562.1 675.5
ROR Total 355.1 364.7 295.7 418.1 429.5 386.5 284.9 216.8 232.8 230.2 203.7 296.8 309.6
Total 1,064.0 1,190.4 1,111.0 1,443.5 1,410.4 1,318.8 848.9 603.4 716.3 690.0 564.9 858.9 985.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 138 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021 aMW
Brownlee HCC* 317.6 356.8 343.3 439.9 434.6 418.1 248.4 163.5 204.4 195.9 153.1 248.5 293.7
Oxbow HCC 131.0 154.3 156.0 191.4 177.1 169.8 105.4 74.7 92.9 89.1 69.2 104.6 126.3
Hells Canyon HCC 257.7 306.2 314.9 392.0 365.9 342.7 208.9 147.0 182.4 175.7 137.9 207.4 253.2
1000 Springs ROR**25.5 26.9 26.4 60.5 87.5 95.1 84.1 65.0 42.4 18.0 - 15.6 45.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 49.2 50.7 41.9 54.0 51.1 44.8 35.2 28.0 36.6 39.7 36.8 44.3 42.7
C .J. Strike ROR 64.4 65.0 56.4 69.4 66.4 54.3 36.4 31.1 43.6 50.6 48.4 55.7 53.5
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.7 34.9 27.6 38.5 37.0 30.8 22.8 15.7 22.8 25.6 23.0 29.5 28.6
Milner ROR 41.1 42.9 21.4 43.0 42.0 26.9 6.2 - - - - 24.9 20.7
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.8 21.1 18.4 22.3 21.4 17.7 12.8 10.9 14.7 16.7 16.0 18.2 17.6
Twin Falls ROR 41.3 43.0 23.4 45.9 41.3 28.5 10.5 - - 6.6 6.0 26.9 22.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 17.8 19.1 17.5 19.2 13.9 8.6 13.8 15.8 13.8 19.0 16.4
Upper Salmon 3&4 ROR 17.7 17.7 16.4 17.7 17.7 16.2 13.1 8.6 13.0 14.7 13.0 17.5 15.3
HCC Total 706.3 817.3 814.2 1,023.3 977.5 930.6 562.7 385.2 479.6 460.7 360.2 560.5 673.2
ROR Total 353.4 362.0 292.2 415.8 427.9 384.7 284.1 215.7 231.0 228.5 194.6 291.4 306.8
Total 1,059.7 1,179.3 1,106.4 1,439.1 1,405.4 1,315.3 846.8 600.9 710.6 689.2 554.8 851.9 980.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022 aMW
Brownlee HCC* 316.4 353.8 342.8 438.9 433.0 417.3 247.7 162.8 201.2 196.4 153.6 247.3 292.6
Oxbow HCC 130.5 153.0 155.7 191.0 176.8 169.5 105.1 74.4 91.1 89.0 69.4 104.1 125.8
Hells Canyon HCC 256.8 303.7 314.4 391.2 364.6 342.1 208.3 146.4 178.9 175.5 138.2 206.4 252.2
1000 Springs ROR**24.7 26.5 26.1 60.3 87.3 95.1 84.1 65.0 42.3 17.5 - 14.3 45.3
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 48.9 50.0 41.4 53.8 50.9 44.5 35.0 27.8 36.4 39.5 36.6 43.4 42.4
C .J. Strike ROR 64.0 65.0 56.0 69.1 66.1 54.0 36.2 30.8 43.3 50.3 47.8 54.5 53.1
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.4 34.7 27.3 38.2 36.8 30.4 22.6 15.6 22.6 25.4 22.8 29.3 28.3
Milner ROR 40.6 42.3 18.8 42.8 41.7 26.2 6.2 - - - - 24.9 20.3
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.4 21.0 18.3 22.2 21.3 17.6 12.8 10.8 14.6 16.4 15.8 17.9 17.4
Twin Falls ROR 40.1 41.4 21.6 45.8 41.1 28.3 10.5 - - 6.6 6.0 26.9 22.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 17.6 19.1 17.5 19.2 13.8 8.5 13.7 15.7 13.7 18.8 16.3
Upper Salmon 3&4 ROR 17.7 17.7 16.3 17.7 17.7 16.2 13.0 8.5 12.9 14.6 12.9 17.3 15.2
HCC Total 703.7 810.5 812.9 1,021.1 974.4 928.9 561.1 383.6 471.2 460.9 361.2 557.8 670.6
ROR Total 349.5 358.4 285.9 414.4 426.4 382.7 283.3 214.8 230.0 226.8 193.2 287.1 304.4
Total 1,053.2 1,168.9 1,098.8 1,435.5 1,400.8 1,311.6 844.4 598.4 701.2 687.7 554.4 844.9 975.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 139
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023 aMW
Brownlee HCC* 315.3 351.6 342.5 438.1 431.7 416.5 247.1 162.2 198.5 196.2 153.6 246.7 291.7
Oxbow HCC 130.1 152.1 155.6 190.6 176.5 169.2 104.8 74.1 89.7 88.7 69.3 103.8 125.4
Hells Canyon HCC 255.9 301.9 314.2 390.5 363.6 341.5 207.8 145.8 176.2 175.0 138.1 205.9 251.4
1000 Springs ROR**24.5 25.6 25.9 60.0 87.1 95.1 84.1 64.9 42.3 17.4 - 13.8 45.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 48.7 48.8 41.3 53.6 50.7 44.2 34.9 27.6 36.2 39.3 36.4 42.5 42.0
C .J. Strike ROR 63.6 64.6 55.9 68.8 65.8 53.8 36.0 30.6 43.0 50.1 47.6 53.3 52.8
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.2 34.0 27.1 37.8 36.6 30.0 22.5 15.4 22.4 25.3 22.6 28.5 28.0
Milner ROR 40.3 40.7 18.5 42.5 41.4 25.4 6.2 - - - - 23.9 19.9
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.3 20.9 18.2 22.1 21.3 17.6 12.7 10.7 14.5 16.4 15.8 17.5 17.3
Twin Falls ROR 39.9 40.8 21.3 45.6 40.9 27.8 10.5 - - 6.6 6.0 25.4 22.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 17.4 19.1 17.5 19.2 13.7 8.4 13.5 15.6 13.5 18.2 16.2
Upper Salmon 3&4 ROR 17.7 17.7 16.1 17.7 17.7 16.2 12.9 8.4 12.7 14.5 12.8 16.8 15.1
HCC Total 701.3 805.6 812.3 1,019.2 971.7 927.2 559.7 382.1 464.4 459.9 361.0 556.4 668.4
ROR Total 347.9 352.9 284.2 412.6 425.0 380.5 282.6 213.8 228.7 226.0 192.3 279.7 302.2
Total 1,049.2 1,158.5 1,096.5 1,431.8 1,396.7 1,307.7 842.3 595.9 693.1 685.9 553.3 836.1 970.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024 aMW
Brownlee HCC* 314.2 350.3 345.8 437.2 430.1 415.7 246.5 161.5 196.3 196.1 153.6 245.6 291.1
Oxbow HCC 129.6 151.5 157.0 190.3 176.3 168.9 104.6 73.8 88.6 88.6 69.3 103.3 125.1
Hells Canyon HCC 255.0 300.9 317.0 389.8 362.4 340.9 207.3 145.2 174.0 174.8 138.0 205.0 250.9
1000 Springs ROR**24.3 25.4 25.6 59.8 86.9 95.0 84.1 64.9 42.1 17.4 - 13.8 44.9
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 48.4 48.4 41.1 53.4 50.5 43.8 34.7 27.4 35.9 39.0 36.3 41.7 41.7
C .J. Strike ROR 63.2 64.2 55.7 68.5 65.5 53.5 35.8 30.3 42.6 49.6 47.3 52.5 52.4
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 34.0 33.7 26.9 37.5 36.4 29.6 22.4 15.2 22.2 25.1 22.4 27.6 27.8
Milner ROR 40.1 40.4 18.1 42.2 41.1 24.9 6.2 - - - - 21.7 19.6
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.2 20.2 18.1 22.0 21.2 17.5 12.6 10.6 14.4 16.3 15.7 17.3 17.2
Twin Falls ROR 39.6 40.5 20.9 45.4 40.6 27.3 10.5 - - 6.6 6.0 23.5 21.7
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 17.2 19.1 17.5 19.2 13.5 8.3 13.3 15.4 13.4 17.5 16.1
Upper Salmon 3&4 ROR 17.7 17.7 15.9 17.7 17.7 16.2 12.8 8.3 12.6 14.4 12.7 16.2 15.0
HCC Total 698.8 802.7 819.8 1,017.3 968.7 925.5 558.4 380.5 458.8 459.5 360.9 553.9 667.1
ROR Total 346.2 350.3 282.0 411.0 423.4 378.2 281.7 212.8 227.3 224.6 191.4 271.6 300.0
Total 1,045.0 1,153.0 1,101.8 1,428.3 1,392.1 1,303.7 840.1 593.3 686.1 684.1 552.3 825.5 967.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 140 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025 aMW
Brownlee HCC* 313.2 349.2 344.9 436.5 429.4 415.0 245.9 160.9 194.4 196.1 153.8 244.7 290.3
Oxbow HCC 129.2 151.1 156.7 190.0 175.8 168.6 104.3 73.5 87.6 88.5 69.4 103.0 124.8
Hells Canyon HCC 254.2 300.0 316.2 389.2 361.8 340.3 206.8 144.7 172.1 174.6 138.2 204.3 250.2
1000 Springs ROR**23.9 25.2 25.4 59.5 86.7 94.7 84.1 64.9 42.0 17.3 - 13.4 44.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 48.1 48.1 40.9 53.2 50.3 43.5 34.5 27.2 35.7 38.9 36.0 41.0 41.5
C .J. Strike ROR 62.9 63.8 55.3 68.2 65.3 53.3 35.6 30.1 42.3 49.4 47.1 51.4 52.1
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 33.6 33.5 26.7 37.2 36.2 29.3 22.2 15.1 21.9 24.9 22.3 26.9 27.5
Milner ROR 39.5 40.3 17.8 42.0 40.8 24.6 6.2 - - - - 20.0 19.3
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.1 20.0 18.0 21.9 21.1 17.4 12.6 10.6 14.3 16.2 15.6 17.0 17.1
Twin Falls ROR 39.1 40.3 20.6 45.2 40.4 27.0 10.5 - - 6.6 6.0 22.0 21.5
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 17.1 19.1 17.5 18.9 13.4 8.1 13.1 15.3 13.3 16.9 15.9
Upper Salmon 3&4 ROR 17.7 17.7 15.8 17.7 17.7 16.2 12.7 8.2 12.4 14.3 12.6 15.7 14.9
HCC Total 696.6 800.3 817.8 1,015.7 967.0 923.9 557.0 379.1 454.0 459.2 361.4 552.0 665.3
ROR Total 343.6 348.7 280.1 409.4 422.0 376.1 280.9 212.0 225.9 223.7 190.5 264.1 298.1
Total 1,040.2 1,149.0 1,097.9 1,425.1 1,389.0 1,300.0 837.9 591.1 679.9 682.9 551.9 816.1 963.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026 aMW
Brownlee HCC* 312.2 348.2 343.9 435.7 429.4 414.2 245.3 160.3 192.5 196.0 153.8 244.5 289.7
Oxbow HCC 128.8 150.6 156.2 189.6 175.8 168.2 104.0 73.2 86.6 88.3 69.3 102.9 124.5
Hells Canyon HCC 253.4 299.1 315.4 388.5 361.8 339.7 206.3 144.1 170.2 174.2 138.1 204.1 249.6
1000 Springs ROR**23.7 25.0 25.1 59.3 86.6 94.4 84.0 64.8 42.0 17.9 - 12.4 44.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 47.6 47.9 40.6 53.0 50.1 43.2 34.5 27.0 35.4 38.7 35.9 40.3 41.2
C .J. Strike ROR 62.6 63.0 54.7 67.9 64.3 52.9 35.3 29.9 42.0 49.1 46.6 50.4 51.6
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 33.2 33.3 26.5 36.9 36.0 29.2 22.1 14.9 21.7 24.7 22.1 26.2 27.2
Milner ROR 39.3 40.1 17.5 41.7 40.6 24.2 6.2 - - - - 18.0 19.0
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 20.0 19.9 17.9 21.8 20.9 17.3 12.5 10.5 14.2 16.2 15.5 16.7 17.0
Twin Falls ROR 38.9 40.1 20.3 45.0 40.2 26.7 10.5 - - 6.6 6.0 20.5 21.2
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.1 19.1 16.9 19.1 17.5 18.9 13.3 8.0 13.0 15.1 13.1 16.4 15.8
Upper Salmon 3&4 ROR 17.7 17.7 15.7 17.7 17.7 16.2 12.6 8.1 12.3 14.2 12.4 15.2 14.8
HCC Total 694.4 797.9 815.5 1,013.8 967.0 922.1 555.6 377.6 449.3 458.5 361.2 551.5 663.7
ROR Total 341.7 346.8 277.7 407.8 419.9 374.2 280.1 211.0 224.7 223.3 189.2 255.9 296.0
Total 1,036.1 1,144.7 1,093.2 1,421.6 1,386.8 1,296.3 835.7 588.6 674.0 681.8 550.4 807.4 959.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 141
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027 aMW
Brownlee HCC* 311.1 347.2 343.1 434.9 429.0 413.4 244.6 159.7 190.0 196.6 154.2 242.7 288.9
Oxbow HCC 128.4 150.2 155.9 189.3 175.6 167.9 103.8 72.9 85.3 88.4 69.5 102.1 124.1
Hells Canyon HCC 252.6 298.3 314.7 387.9 361.5 339.1 205.7 143.5 167.7 174.4 138.4 202.6 248.9
1000 Springs ROR**23.6 24.8 24.9 59.1 86.4 94.2 84.0 64.8 41.9 17.3 - 11.4 44.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 47.4 47.6 40.4 52.1 49.9 42.9 34.4 26.8 35.2 38.4 35.9 39.6 40.9
C .J. Strike ROR 62.0 61.5 54.0 67.6 63.9 52.5 35.1 29.6 41.7 48.9 46.3 49.2 51.0
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 33.0 33.0 26.0 36.6 35.8 29.1 22.0 14.8 21.5 24.5 21.9 25.4 27.0
Milner ROR 39.1 39.8 17.2 40.9 40.3 23.9 6.2 - - - - 16.0 18.6
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.7 12.0 10.8
Swan Falls ROR 19.9 19.8 17.7 21.8 20.7 17.2 12.4 10.4 14.1 16.1 15.4 16.2 16.8
Twin Falls ROR 38.7 39.8 20.0 43.8 40.0 26.4 10.5 - - 6.6 6.0 18.9 20.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.1 16.6 19.1 17.6 18.7 13.2 7.9 12.8 15.0 13.0 15.8 15.7
Upper Salmon 3&4 ROR 17.7 17.7 15.4 17.7 17.7 16.2 12.5 8.0 12.2 14.0 12.3 14.7 14.7
HCC Total 692.1 795.7 813.7 1,012.1 966.1 920.4 554.1 376.1 443.0 459.4 362.1 547.4 661.9
ROR Total 340.2 343.8 274.7 404.1 418.3 372.3 279.4 210.1 223.6 221.6 188.4 247.0 293.6
Total 1,032.3 1,139.5 1,088.4 1,416.2 1,384.4 1,292.7 833.5 586.2 666.6 681.0 550.5 794.4 955.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028 aMW
Brownlee HCC* 310.1 346.1 340.1 434.1 427.8 412.6 244.0 159.0 188.1 196.7 153.9 242.1 287.9
Oxbow HCC 128.0 149.8 154.6 189.0 175.1 167.6 103.5 72.6 84.3 88.4 69.3 101.8 123.7
Hells Canyon HCC 251.8 297.4 312.2 387.2 360.6 338.5 205.3 143.0 165.8 174.3 138.0 202.1 248.0
1000 Springs ROR**23.5 24.6 23.9 58.2 86.3 94.0 84.0 64.7 41.9 17.0 - 10.4 44.0
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 47.1 47.3 39.8 51.8 49.7 42.6 34.3 26.7 34.9 38.2 35.7 38.9 40.6
C .J. Strike ROR 61.3 61.1 53.0 67.3 63.5 52.1 34.9 29.4 41.3 48.5 46.1 48.1 50.6
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 32.7 32.8 25.5 36.4 35.4 28.8 21.8 14.6 21.3 24.4 21.8 24.7 26.7
Milner ROR 38.9 39.5 16.2 43.5 40.2 23.6 6.2 - - - - 14.4 18.5
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.7 19.7 17.5 21.7 20.4 17.1 12.4 10.3 14.2 16.0 15.3 15.9 16.7
Twin Falls ROR 38.5 39.6 18.7 42.3 39.8 26.2 10.5 - - 6.6 5.9 17.3 20.5
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 16.1 19.1 17.6 18.5 13.1 7.8 12.6 14.9 12.9 15.2 15.5
Upper Salmon 3&4 ROR 17.7 17.7 15.0 17.7 17.7 16.2 12.4 7.9 12.0 13.9 12.2 14.2 14.6
HCC Total 689.9 793.3 806.9 1,010.3 963.5 918.7 552.8 374.6 438.1 459.4 361.2 546.0 659.6
ROR Total 338.2 342.2 268.2 403.4 416.6 370.3 278.7 209.2 222.3 220.3 187.4 238.9 291.3
Total 1,028.1 1,135.5 1,075.1 1,413.7 1,380.0 1,289.0 831.5 583.8 660.4 679.7 548.6 784.9 950.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 142 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029 aMW
Brownlee HCC* 309.1 345.1 339.7 433.4 427.0 411.9 243.5 158.4 185.8 197.0 154.2 241.1 287.2
Oxbow HCC 127.6 149.3 154.4 188.7 174.8 167.3 103.3 72.3 83.2 88.3 69.4 101.4 123.3
Hells Canyon HCC 251.0 296.6 311.8 386.6 359.9 337.9 204.8 142.5 163.6 174.3 138.2 201.2 247.4
1000 Springs ROR** 23.3 24.5 23.7 58.0 85.8 93.8 84.0 64.7 41.8 17.3 - 9.4 43.9
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 46.9 47.1 39.5 51.6 49.5 42.3 34.1 26.5 34.7 38.1 35.4 38.2 40.3
C .J. Strike ROR 61.0 60.8 52.6 66.5 63.2 51.7 34.7 29.2 41.0 48.2 45.8 47.1 50.2
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 32.5 32.5 25.0 36.1 34.2 28.5 21.7 14.4 21.1 24.2 21.5 24.0 26.3
Milner ROR 38.6 39.3 14.5 42.9 36.4 23.3 6.2 - - - - 12.5 17.8
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.6 19.6 17.3 21.4 20.3 17.0 12.3 10.3 14.1 15.9 15.2 15.6 16.6
Twin Falls ROR 38.3 39.4 18.4 41.8 36.5 25.9 10.5 - - 6.6 5.9 15.8 19.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 15.7 19.1 17.6 18.3 13.0 7.7 12.5 14.8 12.7 14.7 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.7 17.7 17.7 16.2 12.3 7.8 11.9 13.8 12.1 13.8 14.5
HCC Total 687.7 791.0 805.9 1,008.7 961.7 917.1 551.6 373.2 432.6 459.6 361.8 543.7 657.9
ROR Total 336.7 340.8 263.9 400.5 407.2 368.2 277.9 208.4 221.2 219.7 186.1 230.9 288.5
Total 1,024.4 1,131.8 1,069.8 1,409.2 1,368.9 1,285.3 829.5 581.6 653.8 679.3 547.9 774.6 946.3
*HCC=HellsCanyonComplex,**ROR=RunofRiver

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030 aMW
Brownlee HCC* 308.1 344.0 339.3 432.6 426.2 411.0 242.8 157.8 184.7 197.1 153.9 240.3 286.5
Oxbow HCC 127.1 148.9 154.2 188.3 174.5 167.0 103.0 72.0 82.6 88.3 69.2 101.0 123.0
Hells Canyon HCC 250.2 295.7 311.5 385.9 359.3 337.3 204.3 141.9 162.4 174.2 137.9 200.5 246.8
1000 Springs ROR**23.1 24.3 23.4 57.8 85.8 93.7 84.0 64.7 41.7 17.2 - 8.4 43.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 46.7 46.8 38.9 51.4 49.3 42.0 34.0 26.3 34.4 38.0 35.4 37.5 40.1
C .J. Strike ROR 60.7 60.4 52.3 66.1 62.9 51.3 34.5 28.9 40.7 48.0 45.5 46.7 49.8
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 32.3 32.1 25.0 35.8 34.0 28.3 21.6 14.3 20.8 24.1 21.3 23.7 26.1
Milner ROR 38.4 39.0 13.5 42.6 36.2 23.0 6.2 - - - - 11.4 17.5
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.5 19.5 17.2 21.3 20.2 16.9 12.2 10.2 14.0 15.9 15.4 15.6 16.5
Twin Falls ROR 38.1 39.1 17.2 41.4 36.2 25.6 10.5 - - 6.6 5.9 14.2 19.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 15.7 19.1 17.6 18.1 12.9 7.5 12.3 14.6 12.5 14.5 15.3
Upper Salmon 3&4 ROR 17.7 17.7 14.7 17.7 17.7 16.2 12.3 7.7 11.7 13.7 11.9 13.6 14.4
HCC Total 685.4 788.6 805.0 1,006.8 959.9 915.3 550.1 371.7 429.7 459.6 361.0 541.8 656.2
ROR Total 335.3 338.8 260.4 398.6 405.9 366.3 277.3 207.4 219.7 218.9 185.4 225.4 286.6
Total 1,020.7 1,127.4 1,065.4 1,405.4 1,365.8 1,281.6 827.4 579.1 649.4 678.5 546.4 767.2 942.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 143
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031 aMW
Brownlee HCC* 307.1 343.0 338.8 431.9 425.3 410.3 242.3 157.2 179.2 197.0 154.4 239.4 285.5
Oxbow HCC 126.7 148.5 154.0 188.0 174.2 166.7 102.8 71.7 81.7 88.1 69.4 100.7 122.7
Hells Canyon HCC 249.4 294.8 311.0 385.3 358.6 336.8 203.8 141.3 160.4 173.8 138.3 199.8 246.1
1000 Springs ROR**23.0 23.8 22.6 57.0 85.8 93.5 84.0 64.6 41.7 17.3 - 7.4 43.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 46.4 46.5 38.6 51.2 49.1 42.0 33.8 26.1 34.2 37.8 35.3 36.8 39.8
C .J. Strike ROR 60.3 60.0 52.0 65.2 62.7 50.9 34.3 28.7 40.5 47.7 45.3 46.5 49.5
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 32.1 31.9 24.9 35.5 33.8 28.0 21.4 14.1 20.6 23.9 21.2 23.7 25.9
Milner ROR 38.2 38.5 13.5 42.0 35.9 22.6 6.2 - - - - 9.8 17.2
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.4 19.4 17.1 21.1 20.1 16.7 12.2 10.1 13.9 15.8 15.3 15.6 16.4
Twin Falls ROR 38.0 38.2 16.8 40.9 36.0 25.3 10.5 - - 6.6 5.9 12.6 19.2
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 15.6 19.1 17.6 17.9 12.8 7.4 12.1 14.5 12.4 14.5 15.2
Upper Salmon 3&4 ROR 17.7 17.7 14.6 17.7 17.7 16.2 12.2 7.6 11.6 13.6 11.8 13.6 14.3
HCC Total 683.2 786.3 803.8 1,005.2 958.1 913.8 548.9 370.2 421.2 458.9 362.1 539.9 654.3
ROR Total 333.9 335.9 258.2 395.1 404.7 364.3 276.5 206.4 218.7 218.0 184.7 220.3 284.7
Total 1,017.1 1,122.2 1,062.0 1,400.3 1,362.7 1,278.1 825.4 576.6 639.9 676.9 546.8 760.2 939.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032 aMW
Brownlee HCC* 306.1 342.0 338.4 431.1 424.6 409.3 241.7 156.5 177.0 197.3 154.3 238.7 284.7
Oxbow HCC 126.3 148.0 153.8 187.7 173.9 166.3 102.5 71.4 80.5 88.1 69.3 100.4 122.3
Hells Canyon HCC 248.6 294.0 310.7 384.7 358.0 335.9 203.4 140.8 158.1 173.8 138.1 199.2 245.4
1000 Springs ROR**22.9 23.7 21.7 56.8 85.6 93.3 84.0 64.6 41.6 17.2 - 6.4 43.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 46.2 46.3 38.5 51.1 48.9 42.0 33.7 25.9 33.9 37.7 35.1 36.5 39.7
C .J. Strike ROR 60.0 59.7 51.7 64.9 62.4 50.5 34.1 28.4 40.2 47.6 45.1 46.2 49.2
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 31.9 31.7 24.7 35.0 33.7 27.7 21.3 14.0 20.4 23.8 21.0 23.7 25.7
Milner ROR 38.0 38.2 12.5 40.8 35.7 22.3 6.2 - - - - 8.2 16.8
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.4 19.3 17.0 21.0 20.1 16.5 12.1 10.0 13.8 15.7 15.3 15.6 16.3
Twin Falls ROR 37.8 38.0 16.0 39.9 35.8 25.0 10.5 - - 6.6 5.9 11.0 18.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 15.5 19.1 17.6 17.7 12.7 7.3 12.0 14.4 12.3 14.5 15.1
Upper Salmon 3&4 ROR 17.7 17.7 14.5 17.7 17.7 16.2 12.1 7.5 11.4 13.5 11.7 13.6 14.3
HCC Total 681.0 784.0 802.9 1,003.5 956.4 911.5 547.6 368.7 415.6 459.2 361.7 538.3 652.5
ROR Total 332.7 334.5 254.6 391.7 403.5 362.4 275.8 205.5 217.4 217.3 183.9 215.5 282.9
Total 1,013.7 1,118.5 1,057.5 1,395.2 1,359.9 1,273.9 823.4 574.2 633.0 676.5 545.6 753.8 935.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 144 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033 aMW
Brownlee HCC* 305.2 340.9 337.8 430.3 423.7 408.0 241.1 155.9 174.7 197.8 154.3 237.6 283.9
Oxbow HCC 126.0 147.6 153.5 187.4 173.5 165.8 102.3 71.1 79.4 88.2 69.3 99.9 122.0
Hells Canyon HCC 247.9 293.2 310.2 384.0 357.3 334.9 202.9 140.2 155.9 174.0 138.0 198.3 244.7
1000 Springs ROR**22.7 23.5 20.8 56.6 85.4 93.1 83.9 64.5 41.5 16.9 - 5.4 42.9
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 46.0 46.0 38.2 50.9 48.7 42.0 33.5 25.7 33.7 37.4 34.9 36.5 39.5
C .J. Strike ROR 59.7 59.3 51.3 64.6 62.1 50.2 33.9 28.2 39.9 47.4 44.8 46.0 49.0
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 31.7 31.5 23.7 34.5 33.5 27.5 21.2 13.8 20.2 23.6 20.9 23.7 25.5
Milner ROR 37.7 37.9 11.9 38.0 35.4 22.0 6.2 - - - - 6.4 16.3
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.3 19.2 16.9 21.0 20.0 16.4 12.0 9.9 13.7 15.6 15.2 15.6 16.2
Twin Falls ROR 37.6 37.8 14.6 37.4 35.6 24.8 10.5 - - 6.6 5.9 9.6 18.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 14.7 19.1 17.6 17.5 12.6 7.2 11.8 14.3 12.2 14.5 15.0
Upper Salmon 3&4 ROR 17.7 17.7 13.8 17.7 17.7 16.2 12.0 7.4 11.3 13.4 11.7 13.6 14.2
HCC Total 679.1 781.7 801.5 1,001.7 954.4 908.7 546.3 367.2 410.0 460.0 361.6 535.8 650.7
ROR Total 331.2 332.8 248.4 385.2 402.0 360.9 274.9 204.5 216.2 216.0 183.1 211.1 280.5
Total 1,010.3 1,114.5 1,049.9 1,386.9 1,356.4 1,269.6 821.2 571.7 626.2 676.0 544.7 746.9 931.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50 Percentile Water, 50 Percentile Load
Resource Type 1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034 aMW
Brownlee HCC* 304.1 339.2 337.0 429.6 422.9 406.7 240.5 155.3 172.7 197.7 154.7 236.6 283.1
Oxbow HCC 125.5 146.9 153.2 187.1 173.2 165.3 102.0 70.8 78.4 88.0 69.4 99.5 121.6
Hells Canyon HCC 247.1 291.7 309.4 383.4 356.7 333.9 202.4 139.6 154.0 173.7 138.3 197.5 244.0
1000 Springs ROR**22.4 23.3 19.9 56.4 85.3 92.9 83.9 64.5 41.5 16.5 - - 42.2
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 45.7 45.7 38.0 50.7 48.5 41.8 33.3 25.5 33.4 37.2 34.7 36.5 39.3
C .J. Strike ROR 59.4 58.9 51.0 64.3 61.8 50.0 33.7 28.0 39.5 47.1 44.7 45.8 48.7
Cascade ROR 1.5 1.6 2.8 5.9 5.3 12.0 10.2 13.3 8.8 2.0 1.4 1.4 5.5
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 31.5 31.2 23.5 34.3 33.3 27.2 21.0 13.6 20.0 23.4 20.7 23.7 25.3
Milner ROR 37.3 37.6 11.6 36.7 35.2 21.7 6.2 - - - - 6.2 16.0
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.6 12.0 10.8
Swan Falls ROR 19.1 19.1 16.8 20.9 19.9 16.3 12.0 9.9 13.6 15.6 15.2 15.6 16.2
Twin Falls ROR 37.2 37.5 14.3 36.3 35.4 24.5 10.5 - - 6.6 5.9 9.5 18.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 19.2 19.2 14.6 19.1 17.6 17.3 12.5 7.0 11.6 14.1 12.0 14.5 14.9
Upper Salmon 3&4 ROR 17.7 17.7 13.7 17.7 17.7 16.0 11.9 7.3 11.2 13.3 11.5 13.6 14.1
HCC Total 676.7 777.8 799.6 1,000.1 952.7 905.9 544.9 365.7 405.0 459.4 362.4 533.6 648.6
ROR Total 329.1 330.9 245.9 381.8 400.7 358.9 274.1 203.6 214.9 214.6 182.2 205.2 278.5
Total 1,005.8 1,108.7 1,045.5 1,381.9 1,353.3 1,264.8 819.0 569.3 619.9 674.0 544.6 738.8 927.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 145
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015 aMW
Brownlee HCC* 252.2 312.3 252.5 317.5 387.2 263.4 232.9 157.0 191.8 173.5 146.5 214.8 241.8
Oxbow HCC 106.2 131.2 111.4 133.2 160.2 110.8 98.5 71.6 88.8 78.5 65.6 90.0 103.8
Hells Canyon HCC 210.3 258.9 227.3 269.4 325.3 226.7 194.3 140.7 174.0 154.8 130.6 178.3 207.5
1000 Springs ROR**- 15.4 14.2 36.1 71.6 88.4 84.3 62.0 36.3 12.7 - - 35.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 38.1 42.4 38.5 38.9 41.0 39.2 34.7 27.7 36.5 38.9 36.9 37.0 37.5
C .J. Strike ROR 49.7 55.1 50.5 51.0 48.1 45.2 35.4 30.5 43.5 49.3 47.9 48.1 46.2
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.3 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 24.1 29.1 24.2 25.3 27.3 27.1 22.5 15.7 23.1 25.2 23.6 23.5 24.2
Milner ROR 8.9 26.6 10.1 10.4 15.4 15.4 6.2 - - - 3.0 6.2 8.5
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 11.8 12.0 11.0
Swan Falls ROR 16.2 17.9 16.5 17.3 16.1 15.2 12.6 10.7 14.7 16.2 15.8 15.8 15.4
Twin Falls ROR 11.9 27.8 12.5 12.5 18.2 18.4 10.5 - - 6.6 7.8 9.5 11.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.8 18.9 15.1 16.0 17.6 17.2 13.6 8.6 14.1 15.5 14.3 14.3 15.0
Upper Salmon 3&4 ROR 13.9 17.4 14.1 14.9 16.2 15.9 12.9 8.6 13.2 14.5 13.4 13.5 14.0
HCC Total 568.7 702.4 591.2 720.1 872.6 600.9 525.7 369.3 454.5 406.8 342.7 483.1 553.2
ROR Total 217.2 291.1 236.7 263.1 314.2 328.2 279.0 210.4 224.0 219.2 202.3 207.7 249.4
Total 785.9 993.5 827.9 983.2 1,186.8 929.1 804.7 579.7 678.5 626.0 545.0 690.8 802.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016 aMW
Brownlee HCC* 252.7 316.9 254.5 321.2 391.9 265.6 232.6 156.8 190.9 173.3 146.8 214.6 243.1
Oxbow HCC 106.4 133.1 112.3 134.7 162.1 111.8 98.4 71.5 88.4 78.4 65.8 89.9 104.4
Hells Canyon HCC 210.6 262.6 229.0 272.3 329.0 228.6 194.1 140.6 173.3 154.7 130.9 178.1 208.6
1000 Springs ROR**- 18.0 14.1 36.7 71.6 88.5 84.5 62.4 37.1 12.9 - - 35.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 38.0 43.1 38.8 39.0 41.4 39.2 34.6 27.6 36.4 38.8 36.7 36.9 37.5
C .J. Strike ROR 49.8 57.3 50.8 51.2 48.8 45.1 35.4 30.4 43.3 49.2 47.8 48.1 46.4
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.3 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 24.2 30.9 24.8 25.3 27.4 26.9 22.4 15.6 23.0 25.1 23.5 23.5 24.4
Milner ROR 8.9 30.6 11.9 10.8 15.4 15.4 6.2 - - - 3.0 6.2 9.0
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 11.8 12.0 11.0
Swan Falls ROR 16.2 18.1 16.8 17.5 16.1 15.3 12.6 10.7 14.6 16.2 15.8 15.8 15.5
Twin Falls ROR 12.2 31.2 14.6 13.2 18.2 18.8 10.5 - - 6.6 7.8 9.5 11.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.9 19.2 15.6 16.1 17.6 17.1 13.6 8.6 13.9 15.4 14.2 14.3 15.0
Upper Salmon 3&4 ROR 13.9 17.7 14.5 14.9 16.3 15.8 12.8 8.5 13.1 14.4 13.4 13.4 14.1
HCC Total 569.7 712.6 595.8 728.2 882.9 606.0 525.1 368.9 452.5 406.4 343.5 482.6 556.2
ROR Total 217.7 306.6 242.9 265.4 315.6 328.3 278.9 210.4 224.0 218.9 201.8 207.5 251.5
Total 787.4 1,019.2 838.7 993.6 1,198.5 934.3 804.0 579.3 676.5 625.3 545.3 690.1 807.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 146 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017 aMW
Brownlee HCC* 251.4 315.8 256.8 322.5 397.3 269.0 232.8 157.2 189.6 174.0 146.8 216.3 244.1
Oxbow HCC 105.9 132.6 113.3 135.2 164.3 113.2 98.5 71.7 87.6 78.5 65.7 90.6 104.8
Hells Canyon HCC 209.6 261.7 230.9 273.4 333.3 231.3 194.2 140.9 171.8 154.9 130.7 179.5 209.3
1000 Springs ROR**- 19.2 14.2 38.7 71.6 88.5 84.5 62.9 37.5 13.0 - - 35.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.7 44.0 38.5 38.9 41.9 39.4 34.6 27.6 36.3 38.8 36.1 36.4 37.5
C .J. Strike ROR 49.9 57.3 50.2 52.3 49.9 45.5 35.5 30.4 43.2 49.2 47.0 47.6 46.5
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.3 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 24.0 31.3 24.8 25.3 27.6 27.0 22.5 15.7 22.9 25.1 23.2 23.1 24.4
Milner ROR 8.2 31.5 11.1 10.6 15.4 15.4 6.2 - - - - 4.5 8.6
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.9 12.0 10.8
Swan Falls ROR 16.2 18.5 16.4 17.6 16.5 15.4 12.6 10.7 14.6 16.2 15.5 15.7 15.5
Twin Falls ROR 11.2 32.1 13.7 13.0 18.2 19.2 10.5 - - 6.6 6.2 8.5 11.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.7 19.2 15.6 16.1 17.7 17.1 13.6 8.6 13.9 15.4 13.9 14.0 15.0
Upper Salmon 3&4 ROR 13.8 17.7 14.5 14.9 16.4 15.8 12.9 8.6 13.1 14.4 13.1 13.1 14.0
HCC Total 566.9 710.1 601.0 731.1 894.8 613.5 525.5 369.8 448.9 407.4 343.2 486.4 558.2
ROR Total 215.3 311.3 240.0 268.1 318.0 329.5 279.2 211.1 224.2 219.0 192.7 202.7 250.9
Total 782.2 1,021.4 841.0 999.2 1,212.8 943.0 804.7 580.9 673.1 626.4 535.9 689.1 809.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018 aMW
Brownlee HCC* 251.4 315.7 256.4 323.3 399.7 268.5 232.5 156.9 189.0 174.4 146.6 215.6 244.2
Oxbow HCC 105.9 132.6 113.1 135.5 165.2 113.0 98.3 71.6 87.3 78.7 65.6 90.3 104.8
Hells Canyon HCC 209.6 261.7 230.6 274.0 335.1 230.9 194.0 140.6 171.1 155.2 130.5 178.9 209.3
1000 Springs ROR**- 19.1 14.0 39.4 72.1 88.6 84.6 63.1 37.8 14.2 - - 36.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.6 43.0 38.4 39.5 42.4 39.4 34.5 27.5 36.2 38.7 36.1 36.1 37.5
C .J. Strike ROR 49.9 57.0 49.5 52.4 49.9 45.4 35.4 30.3 43.0 49.1 46.9 47.2 46.3
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 24.0 31.2 24.1 25.4 27.5 26.9 22.4 15.6 22.8 25.0 23.1 22.8 24.2
Milner ROR 8.2 31.3 9.6 10.7 15.4 15.4 6.2 - - - - 3.8 8.4
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 9.9 12.0 10.8
Swan Falls ROR 16.2 18.2 16.2 17.7 16.5 15.2 12.6 10.6 14.5 16.1 15.5 15.6 15.4
Twin Falls ROR 11.6 31.8 12.2 13.5 18.2 19.2 10.5 - - 6.6 6.2 8.1 11.5
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.8 19.2 15.1 16.1 17.7 17.0 13.6 8.5 13.8 15.4 13.9 13.8 14.9
Upper Salmon 3&4 ROR 13.8 17.7 14.1 15.0 16.4 15.8 12.8 8.5 13.0 14.3 13.1 13.0 14.0
HCC Total 566.9 710.0 600.1 732.8 900.0 612.4 524.8 369.1 447.4 408.3 342.7 484.8 558.3
ROR Total 215.7 309.0 234.2 270.4 318.9 329.1 278.9 210.7 223.8 219.7 192.5 200.2 250.3
Total 782.6 1,019.0 834.3 1,003.2 1,218.8 941.5 803.7 579.8 671.1 628.0 535.2 685.0 808.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 147
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019 aMW
Brownlee HCC* 252.1 316.1 256.3 324.2 402.8 270.3 233.2 157.3 187.0 174.9 147.1 212.8 244.5
Oxbow HCC 106.2 132.7 113.1 135.9 166.4 113.7 98.6 71.8 86.2 78.6 65.7 89.2 104.8
Hells Canyon HCC 210.2 262.0 230.5 274.7 337.5 232.3 194.6 141.0 169.0 155.2 130.8 176.6 209.5
1000 Springs ROR**- 17.6 14.1 39.7 72.8 88.6 84.6 63.3 37.7 15.0 - - 36.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.9 42.8 36.9 39.3 42.7 39.5 34.7 27.7 36.1 38.8 35.8 35.6 37.3
C .J. Strike ROR 49.9 56.8 47.8 52.3 50.3 45.7 35.7 30.3 42.9 49.1 46.0 46.4 46.1
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 23.9 30.3 22.9 24.6 27.7 27.0 22.5 15.6 22.8 25.1 22.5 22.3 23.9
Milner ROR 8.0 29.0 5.8 8.1 15.4 15.4 6.2 - - - - 1.7 7.5
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.7 10.6
Swan Falls ROR 16.1 17.8 15.8 17.7 16.7 15.4 12.6 10.6 14.5 16.1 15.4 15.4 15.3
Twin Falls ROR 11.3 29.8 9.1 10.9 18.2 19.2 10.5 - - 6.6 4.5 6.8 10.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.7 19.2 14.1 15.5 17.7 17.1 13.7 8.6 13.8 15.4 13.4 13.4 14.7
Upper Salmon 3&4 ROR 13.8 17.7 13.3 14.4 16.5 15.9 12.9 8.6 13.0 14.4 12.7 12.6 13.8
HCC Total 568.5 710.8 599.9 734.8 906.6 616.3 526.4 370.1 442.1 408.7 343.6 478.6 558.9
ROR Total 215.2 301.5 220.8 263.2 320.8 330.0 279.7 211.3 223.5 220.8 186.3 192.7 247.2
Total 783.7 1,012.3 820.7 998.0 1,227.4 946.3 806.1 581.4 665.6 629.5 529.9 671.3 806.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020 aMW
Brownlee HCC* 251.1 315.3 256.2 323.3 401.8 269.0 232.6 156.7 184.5 175.0 147.2 210.1 243.6
Oxbow HCC 105.7 132.4 113.0 135.5 166.1 113.2 98.4 71.4 84.9 78.5 65.7 88.0 104.4
Hells Canyon HCC 209.3 261.3 230.4 274.0 336.8 231.3 194.1 140.4 166.6 155.0 130.7 174.3 208.7
1000 Springs ROR**- 15.6 14.0 39.5 72.7 88.6 84.6 63.2 37.7 15.0 - - 35.9
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.5 42.1 36.7 39.1 42.5 39.3 34.6 27.5 35.9 38.6 35.5 35.5 37.1
C .J. Strike ROR 49.1 54.6 47.5 52.1 50.1 45.4 35.4 30.1 42.6 48.8 45.7 46.2 45.6
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 23.5 29.3 22.6 24.4 27.6 26.9 22.4 15.5 22.5 24.9 22.5 22.2 23.7
Milner ROR 7.7 26.8 5.2 7.8 15.4 15.4 6.2 - - - - 1.9 7.2
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.9 10.6
Swan Falls ROR 16.1 17.5 15.7 17.6 16.5 15.3 12.6 10.6 14.4 16.0 15.3 15.3 15.2
Twin Falls ROR 11.1 27.9 8.6 10.6 18.2 19.2 10.5 - - 6.6 4.5 7.0 10.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.4 19.0 13.9 15.3 17.7 17.0 13.6 8.4 13.6 15.3 13.4 13.3 14.6
Upper Salmon 3&4 ROR 13.5 17.5 13.1 14.3 16.4 15.8 12.8 8.4 12.8 14.3 12.7 12.6 13.7
HCC Total 566.1 709.0 599.6 732.8 904.6 613.5 525.1 368.5 436.0 408.5 343.6 472.4 556.6
ROR Total 212.5 290.8 218.3 261.4 319.8 329.1 279.0 210.3 222.2 219.8 185.6 192.7 245.1
Total 778.6 999.8 817.9 994.2 1,224.4 942.6 804.1 578.8 658.1 628.3 529.2 665.1 801.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 148 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021 aMW
Brownlee HCC* 250.0 314.4 251.5 322.3 400.9 267.8 232.0 156.0 182.3 175.2 147.5 208.5 242.4
Oxbow HCC 105.3 132.0 110.9 135.1 165.7 112.7 98.1 71.1 83.8 78.5 65.8 87.3 103.9
Hells Canyon HCC 208.5 260.6 226.4 273.1 336.1 230.3 193.6 139.9 164.4 154.8 130.9 173.1 207.6
1000 Springs ROR**- 15.2 14.0 39.3 72.5 88.6 84.7 63.0 37.6 15.0 - - 35.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.2 40.6 35.7 38.8 42.4 39.1 34.4 27.3 35.6 38.4 35.3 35.4 36.7
C .J. Strike ROR 48.9 53.2 47.3 51.9 49.9 45.1 35.2 29.8 42.2 48.5 45.5 45.9 45.3
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 23.4 29.0 21.6 24.1 27.5 26.7 22.3 15.3 22.3 24.7 22.3 22.1 23.4
Milner ROR 7.7 26.0 2.4 7.4 15.4 15.4 6.2 - - - - 1.9 6.9
Shoshone Falls ROR 12.0 12.0 10.2 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.9 10.5
Swan Falls ROR 16.0 17.4 15.7 17.5 16.4 15.2 12.5 10.5 14.3 16.0 15.2 15.3 15.2
Twin Falls ROR 10.4 27.3 6.4 10.2 18.2 19.2 10.5 - - 6.6 4.5 7.0 10.0
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.3 18.8 13.1 15.1 17.7 16.9 13.5 8.3 13.4 15.1 13.3 13.2 14.4
Upper Salmon 3&4 ROR 13.4 17.3 12.4 14.2 16.4 15.6 12.7 8.3 12.7 14.1 12.6 12.5 13.5
HCC Total 563.8 707.0 588.8 730.5 902.6 610.8 523.7 367.0 430.4 408.5 344.2 468.9 553.9
ROR Total 210.9 285.3 207.8 259.2 319.1 328.0 278.3 209.1 220.8 218.7 184.7 192.0 242.8
Total 774.7 992.3 796.6 989.7 1,221.7 938.8 802.0 576.1 651.2 627.2 528.9 660.9 796.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022 aMW
Brownlee HCC* 249.1 313.6 250.6 321.3 400.0 266.6 231.3 155.4 180.2 175.6 147.2 207.6 241.5
Oxbow HCC 104.9 131.7 110.5 134.7 165.3 112.2 97.8 70.8 82.6 78.5 65.6 86.9 103.5
Hells Canyon HCC 207.7 260.0 225.6 272.3 335.3 229.3 193.0 139.3 162.2 155.0 130.5 172.2 206.9
1000 Springs ROR**- 15.4 13.6 39.0 72.3 88.6 84.6 62.8 37.5 15.0 - - 35.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 37.1 40.7 35.7 38.6 41.9 38.9 34.4 27.1 35.4 38.2 35.3 35.2 36.5
C .J. Strike ROR 48.6 53.3 47.1 51.7 49.7 44.9 35.0 29.6 41.9 48.3 45.5 45.7 45.1
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 23.1 29.1 21.5 23.9 27.4 26.5 22.1 15.2 22.1 24.5 22.1 21.9 23.3
Milner ROR 7.7 25.8 - 7.0 15.4 15.4 6.2 - - - - 1.9 6.6
Shoshone Falls ROR 12.0 12.0 9.5 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.9 10.4
Swan Falls ROR 15.9 17.5 15.6 17.4 16.4 15.2 12.4 10.4 14.2 15.9 15.4 15.4 15.1
Twin Falls ROR 10.4 27.4 5.8 9.9 18.2 19.2 10.5 - - 6.6 4.5 7.0 10.0
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 14.0 18.8 13.1 15.0 17.6 16.7 13.4 8.2 13.3 15.0 13.1 13.1 14.3
Upper Salmon 3&4 ROR 13.2 17.3 12.4 14.0 16.3 15.5 12.6 8.2 12.6 14.0 12.4 12.4 13.4
HCC Total 561.7 705.3 586.7 728.3 900.6 608.1 522.1 365.5 424.9 409.1 343.3 466.7 551.9
ROR Total 209.6 285.8 203.3 257.2 318.0 327.1 277.5 208.1 219.7 217.8 184.3 191.3 241.6
Total 771.3 991.1 790.0 985.5 1,218.5 935.2 799.6 573.6 644.6 626.9 527.6 658.0 793.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 149
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023 aMW
Brownlee HCC* 247.9 312.3 250.1 320.3 399.2 265.3 230.7 154.8 177.7 175.8 147.5 204.3 240.5
Oxbow HCC 104.4 131.2 110.4 134.3 165.0 111.6 97.6 70.5 81.4 78.5 65.7 85.5 103.0
Hells Canyon HCC 206.8 259.0 225.3 271.6 334.7 228.3 192.5 138.7 159.7 154.9 130.7 169.5 206.0
1000 Springs ROR**- 12.7 13.5 38.8 72.0 88.6 84.7 62.7 36.9 14.8 - - 35.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.9 37.9 35.7 38.3 41.8 38.7 34.2 26.9 35.1 38.0 35.2 35.0 36.1
C .J. Strike ROR 48.3 52.6 46.9 51.6 49.1 44.6 34.8 29.4 41.6 48.0 45.3 45.1 44.8
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.7 27.4 21.4 23.7 27.2 26.4 22.0 15.0 21.9 24.4 21.9 21.7 23.0
Milner ROR 7.7 21.2 - 6.7 15.4 15.4 6.2 - - - - 1.9 6.2
Shoshone Falls ROR 12.0 12.0 9.5 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.9 10.4
Swan Falls ROR 15.8 17.0 15.6 17.4 16.3 15.2 12.4 10.3 14.1 15.8 15.3 15.3 15.0
Twin Falls ROR 10.4 23.3 5.8 9.8 18.2 19.2 10.5 - - 6.6 4.5 7.0 9.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.8 17.5 13.0 14.8 17.5 16.6 13.3 8.1 13.1 14.9 13.0 12.9 14.0
Upper Salmon 3&4 ROR 13.0 16.2 12.3 13.9 16.2 15.4 12.5 8.1 12.4 13.9 12.3 12.3 13.2
HCC Total 559.1 702.5 585.8 726.2 898.8 605.2 520.8 364.0 418.7 409.2 343.9 459.3 549.5
ROR Total 208.2 266.3 202.7 255.7 316.4 326.3 276.9 207.1 217.8 216.7 183.5 189.9 239.0
Total 767.3 968.8 788.5 981.9 1,215.2 931.5 797.7 571.1 636.5 625.9 527.4 649.2 788.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024 aMW
Brownlee HCC* 246.6 309.4 249.7 319.4 398.3 263.9 230.1 154.1 174.9 176.2 147.5 200.3 239.2
Oxbow HCC 103.8 130.0 110.2 133.9 164.6 111.0 97.3 70.2 79.9 78.4 65.5 83.8 102.4
Hells Canyon HCC 205.7 256.6 224.9 270.8 334.0 227.2 192.0 138.1 156.9 154.8 130.4 166.2 204.8
1000 Springs ROR**- 10.3 13.0 37.1 71.9 88.6 84.7 62.5 36.9 14.7 - - 35.0
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.7 37.7 35.7 38.1 41.6 38.5 34.0 26.7 34.9 37.8 35.0 34.8 36.0
C .J. Strike ROR 48.0 52.7 46.7 51.3 48.9 44.3 34.6 29.1 41.2 47.8 45.1 44.9 44.6
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.7 26.0 21.3 23.5 27.2 26.2 21.8 14.8 21.7 24.2 21.8 21.6 22.7
Milner ROR 7.7 17.2 2.0 6.2 15.4 15.4 6.2 - - - - 1.9 6.0
Shoshone Falls ROR 12.0 12.0 9.7 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.7 10.4
Swan Falls ROR 15.7 17.1 15.5 17.2 16.3 15.2 12.3 10.2 14.1 15.8 15.2 15.2 15.0
Twin Falls ROR 10.4 20.2 6.0 9.5 18.2 19.2 10.5 - - 6.6 4.5 6.8 9.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.7 16.5 12.9 14.7 17.5 16.5 13.1 8.0 12.9 14.8 12.9 12.8 13.9
Upper Salmon 3&4 ROR 13.0 15.3 12.2 13.8 16.1 15.3 12.4 8.0 12.3 13.8 12.2 12.2 13.1
HCC Total 556.1 696.0 584.8 724.1 896.8 602.1 519.4 362.4 411.7 409.4 343.4 450.3 546.4
ROR Total 207.5 253.5 204.0 252.1 315.9 325.4 275.9 205.9 216.7 215.8 182.7 188.7 237.0
Total 763.6 949.5 788.8 976.2 1,212.7 927.5 795.3 568.3 628.3 625.2 526.1 639.0 783.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 150 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025 aMW
Brownlee HCC* 246.0 308.4 249.3 318.5 397.5 262.2 229.5 153.5 173.2 168.8 147.9 198.8 237.8
Oxbow HCC 103.6 129.6 110.0 133.6 164.3 110.3 97.1 69.9 79.1 78.2 65.7 83.1 102.0
Hells Canyon HCC 205.2 255.9 224.5 270.2 333.4 225.8 191.5 137.6 155.3 154.0 130.7 164.9 204.1
1000 Springs ROR**- 9.0 11.9 37.0 71.8 88.6 84.6 62.2 36.3 14.6 - - 34.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.6 37.6 35.2 37.9 41.5 38.3 33.9 26.5 34.6 37.7 34.8 34.5 35.8
C .J. Strike ROR 47.4 50.7 46.5 51.1 48.7 44.1 34.4 28.9 40.9 47.6 44.7 44.9 44.2
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.6 25.1 21.3 23.4 27.1 26.0 21.7 14.7 21.4 24.1 21.6 21.4 22.5
Milner ROR 7.7 14.8 2.1 5.9 15.4 15.4 6.2 - - - - 1.7 5.8
Shoshone Falls ROR 12.0 12.0 9.8 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.5 10.4
Swan Falls ROR 15.6 16.1 15.4 17.2 16.2 15.1 12.2 10.2 14.1 15.7 15.2 15.2 14.9
Twin Falls ROR 10.4 18.2 6.1 9.3 18.2 19.2 10.5 - - 6.6 4.5 6.6 9.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.7 15.8 12.9 14.6 17.4 16.4 13.0 7.8 12.8 14.6 12.8 12.7 13.7
Upper Salmon 3&4 ROR 12.9 14.7 12.2 13.7 16.1 15.2 12.4 7.9 12.1 13.7 12.1 12.0 12.9
HCC Total 554.8 693.9 583.8 722.3 895.1 598.3 518.1 361.0 407.5 401.0 344.3 446.8 543.9
ROR Total 206.5 242.5 202.4 250.8 315.1 324.5 275.2 204.8 214.9 214.9 181.7 187.3 235.1
Total 761.3 936.4 786.2 973.1 1,210.2 922.8 793.3 565.8 622.4 615.9 526.0 634.1 779.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026 aMW
Brownlee HCC* 245.3 306.0 248.8 317.7 396.7 261.4 228.9 152.8 171.5 168.8 147.9 198.4 237.0
Oxbow HCC 103.3 128.6 109.8 133.2 164.0 110.0 96.8 69.6 78.2 78.2 65.6 83.0 101.7
Hells Canyon HCC 204.6 253.9 224.1 269.5 332.8 225.1 191.0 137.0 153.6 153.9 130.6 164.6 203.4
1000 Springs ROR**- 7.4 11.2 35.9 71.7 88.6 84.6 62.0 35.9 14.5 - - 34.3
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.4 37.2 34.6 37.7 41.4 38.1 33.7 26.3 34.4 37.5 34.6 34.2 35.5
C .J. Strike ROR 47.2 49.3 46.3 50.9 48.2 43.7 34.2 28.6 40.7 47.4 44.6 44.6 43.8
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.5 22.7 21.1 22.5 27.0 25.8 21.6 14.5 21.2 23.9 21.5 21.3 22.1
Milner ROR 7.7 10.7 2.0 5.2 15.4 15.4 6.2 - - - - 1.8 5.4
Shoshone Falls ROR 12.0 12.0 9.7 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.5 10.4
Swan Falls ROR 15.6 16.0 15.3 17.1 16.0 14.9 12.1 10.1 14.0 15.6 15.1 15.1 14.7
Twin Falls ROR 10.4 12.6 6.0 8.5 18.2 18.8 10.5 - - 6.6 4.5 6.7 8.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.6 13.9 12.7 13.9 17.3 16.2 12.9 7.7 12.6 14.5 12.6 12.6 13.4
Upper Salmon 3&4 ROR 12.8 13.1 12.1 13.1 16.0 15.1 12.3 7.8 12.0 13.6 12.0 11.9 12.7
HCC Total 553.2 688.5 582.7 720.4 893.5 596.5 516.7 359.4 403.2 400.9 344.1 446.0 542.1
ROR Total 205.8 223.4 200.0 245.5 313.9 322.8 274.4 203.6 213.5 213.9 180.9 186.5 232.0
Total 759.0 911.9 782.7 965.9 1,207.4 919.3 791.1 563.0 616.7 614.8 525.0 632.5 774.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 151
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027 aMW
Brownlee HCC* 244.3 301.9 248.3 316.9 395.9 260.6 228.3 152.2 169.6 169.1 147.9 197.8 236.1
Oxbow HCC 102.9 126.9 109.5 132.9 163.7 109.7 96.6 69.3 77.2 78.2 65.6 82.7 101.3
Hells Canyon HCC 203.8 250.6 223.7 268.9 332.2 224.5 190.5 136.4 151.7 153.9 130.6 164.1 202.6
1000 Springs ROR**- - 11.1 34.8 71.7 88.6 84.7 61.8 35.2 14.3 - - 33.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.3 37.0 34.5 37.5 41.2 37.9 33.6 26.1 34.1 37.4 34.2 34.0 35.3
C .J. Strike ROR 47.0 48.6 45.8 50.7 48.1 43.6 34.0 28.4 40.3 47.1 44.4 44.5 43.5
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.4 22.7 20.9 22.5 26.9 25.7 21.4 14.4 21.0 23.8 21.3 21.1 22.0
Milner ROR 7.7 8.2 1.7 4.9 15.4 15.4 6.2 - - - - 1.7 5.1
Shoshone Falls ROR 12.0 12.0 9.7 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.4 10.4
Swan Falls ROR 15.5 15.8 15.4 17.0 16.0 14.8 12.1 10.0 13.9 15.5 15.0 15.0 14.7
Twin Falls ROR 10.4 11.6 6.0 8.5 18.2 18.8 10.5 - - 6.6 4.5 6.6 8.5
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.5 13.9 12.6 13.8 17.2 16.1 12.8 7.6 12.4 14.4 12.5 12.4 13.3
Upper Salmon 3&4 ROR 12.7 13.1 12.0 13.0 16.0 15.0 12.2 7.7 11.8 13.6 11.9 11.8 12.6
HCC Total 551.0 679.4 581.5 718.7 891.8 594.8 515.4 357.9 398.4 401.2 344.1 444.6 539.9
ROR Total 205.1 211.4 198.7 243.4 313.4 322.1 273.8 202.6 211.4 213.0 179.8 185.3 230.0
Total 756.1 890.8 780.2 962.1 1,205.2 916.9 789.2 560.5 609.8 614.2 523.9 629.9 769.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028 aMW
Brownlee HCC* 243.3 299.7 247.9 316.0 395.2 259.9 227.7 151.6 167.3 169.6 148.0 196.7 235.2
Oxbow HCC 102.4 126.0 109.4 132.5 163.4 109.4 96.3 69.0 76.1 78.3 65.6 82.3 100.9
Hells Canyon HCC 202.9 248.8 223.3 268.2 331.6 223.9 190.0 135.9 149.4 154.1 130.6 163.2 201.8
1000 Springs ROR**- - 11.0 36.0 71.7 88.6 84.7 61.5 34.9 14.2 - - 33.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.2 36.7 34.3 37.3 41.0 37.7 33.4 26.0 33.9 37.2 34.0 34.0 35.1
C .J. Strike ROR 46.8 48.4 45.4 50.6 47.9 43.5 33.8 28.1 40.0 46.9 44.2 44.3 43.3
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.3 22.5 20.8 22.4 26.8 25.5 21.3 14.2 20.8 23.7 20.9 20.9 21.8
Milner ROR 7.6 8.2 - 4.7 15.4 15.4 6.2 - - - - 1.7 4.9
Shoshone Falls ROR 12.0 12.0 8.8 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 10.1 10.3
Swan Falls ROR 15.4 15.7 15.4 16.9 16.0 14.8 12.0 9.9 13.8 15.5 15.0 15.0 14.6
Twin Falls ROR 10.4 11.6 5.2 8.4 18.2 18.8 10.5 - - 6.6 4.5 6.3 8.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.4 13.7 12.5 13.8 17.2 16.0 12.7 7.5 12.3 14.3 12.2 12.3 13.2
Upper Salmon 3&4 ROR 12.7 12.9 11.9 13.0 15.9 14.9 12.1 7.6 11.7 13.4 11.7 11.7 12.5
HCC Total 548.6 674.5 580.6 716.7 890.1 593.2 514.0 356.5 392.7 402.0 344.2 442.2 537.9
ROR Total 204.4 210.2 194.3 243.8 312.8 321.4 273.0 201.4 210.1 212.1 178.5 184.1 228.8
Total 753.0 884.7 774.9 960.5 1,202.9 914.6 787.0 557.9 602.8 614.1 522.7 626.3 766.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 152 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029 aMW
Brownlee HCC* 242.7 298.5 247.5 315.1 394.4 259.1 227.1 151.1 161.7 169.4 148.1 196.1 234.2
Oxbow HCC 102.2 125.5 109.2 132.2 163.1 109.0 96.1 68.8 75.1 78.1 65.6 82.0 100.6
Hells Canyon HCC 202.5 247.9 223.0 267.5 331.0 223.3 189.6 135.5 147.4 153.7 130.6 162.7 201.2
1000 Springs ROR**- - 10.7 34.9 71.7 88.6 84.7 61.4 34.8 14.1 - - 33.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 36.1 36.1 34.2 36.6 40.9 37.5 33.3 25.8 33.6 37.0 33.8 33.8 34.9
C .J. Strike ROR 46.6 48.2 45.3 50.4 47.8 43.2 33.6 27.8 39.7 46.6 44.0 44.0 43.1
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.1 22.0 20.7 21.7 26.7 25.3 21.2 14.0 20.6 23.5 20.8 20.7 21.6
Milner ROR 7.6 8.0 - 4.5 15.4 15.3 6.2 - - - - 1.6 4.9
Shoshone Falls ROR 12.0 12.0 8.8 12.0 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.7 10.2
Swan Falls ROR 15.3 15.6 15.3 16.8 16.0 14.7 11.9 9.8 13.7 15.5 14.9 14.9 14.5
Twin Falls ROR 10.4 11.3 5.2 8.4 18.2 18.8 10.5 - - 6.6 4.5 6.0 8.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.3 13.4 12.4 13.2 17.1 15.8 12.6 7.3 12.1 14.2 12.1 12.1 13.0
Upper Salmon 3&4 ROR 12.6 12.6 11.8 12.5 15.8 14.7 12.0 7.5 11.6 13.3 11.5 11.6 12.3
HCC Total 547.4 671.9 579.7 714.8 888.4 591.4 512.8 355.4 384.1 401.2 344.3 440.8 536.0
ROR Total 203.6 207.7 193.4 239.7 312.3 320.1 272.3 200.2 208.8 211.1 177.6 182.2 227.4
Total 751.0 879.6 773.1 954.5 1,200.7 911.5 785.1 555.6 592.9 612.3 521.9 623.0 763.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030 aMW
Brownlee HCC* 242.1 297.7 247.0 314.3 393.6 258.4 226.5 151.0 159.8 169.5 148.2 195.0 233.6
Oxbow HCC 101.9 125.2 109.0 131.9 162.8 108.7 95.8 68.8 74.1 78.1 65.6 81.5 100.3
Hells Canyon HCC 202.0 247.2 222.6 266.8 330.4 222.7 189.0 135.4 145.5 153.7 130.7 161.8 200.6
1000 Springs ROR**- - 10.4 34.7 71.6 88.5 84.7 61.4 34.8 14.2 - - 33.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 35.8 35.9 34.1 35.7 40.8 37.3 33.1 25.6 33.4 36.8 33.6 33.5 34.6
C .J. Strike ROR 46.2 47.9 45.1 49.0 47.6 42.9 33.3 27.6 39.4 46.4 43.7 43.9 42.8
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.0 21.9 20.6 21.3 26.6 25.1 21.0 13.9 20.4 23.3 20.7 20.6 21.5
Milner ROR 7.3 8.0 - 3.1 15.4 15.0 6.2 - - - - 1.6 4.7
Shoshone Falls ROR 12.0 12.0 9.5 11.3 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.7 10.2
Swan Falls ROR 15.2 15.6 15.3 16.5 15.9 14.6 11.9 9.8 13.6 15.4 14.9 14.8 14.5
Twin Falls ROR 10.3 11.3 5.8 7.3 18.1 18.6 10.5 - - 6.6 4.5 6.0 8.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.2 13.3 12.4 12.9 17.0 15.7 12.5 7.2 11.9 14.1 12.0 12.0 12.9
Upper Salmon 3&4 ROR 12.5 12.5 11.8 12.3 15.8 14.6 11.9 7.4 11.4 13.2 11.5 11.5 12.2
HCC Total 546.0 670.1 578.6 713.0 886.8 589.8 511.3 355.2 379.3 401.3 344.5 438.3 534.5
ROR Total 202.1 206.9 194.0 232.8 311.6 318.5 271.4 199.5 207.6 210.3 176.9 181.4 226.1
Total 748.1 877.0 772.6 945.8 1,198.3 908.3 782.7 554.7 586.9 611.6 521.4 619.7 760.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 153
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031 aMW
Brownlee HCC* 241.3 297.0 246.6 313.4 392.9 257.7 225.9 150.7 157.7 169.7 148.2 193.7 232.9
Oxbow HCC 101.6 124.9 108.8 131.5 162.5 108.4 95.5 68.7 72.9 78.0 65.6 81.0 99.9
Hells Canyon HCC 201.3 246.7 222.3 266.1 329.7 222.1 188.5 135.2 143.3 153.6 130.6 160.7 200.0
1000 Springs ROR**- - 10.2 33.2 71.6 88.5 84.7 61.4 34.6 14.1 - - 33.2
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 35.6 35.6 34.0 35.6 40.7 37.1 33.0 25.4 33.1 36.6 33.6 33.4 34.5
C .J. Strike ROR 46.0 47.6 44.9 47.8 47.5 42.5 33.2 27.4 39.1 46.1 43.5 43.6 42.4
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.8 21.7 20.5 21.1 26.5 24.9 20.9 13.7 20.2 23.2 20.5 20.4 21.3
Milner ROR 7.3 8.0 - 2.0 15.3 14.8 6.2 - - - - 1.6 4.6
Shoshone Falls ROR 12.0 12.0 9.2 10.2 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.7 10.1
Swan Falls ROR 15.4 15.5 15.2 16.4 15.9 14.5 11.8 9.7 13.5 15.3 14.8 14.8 14.4
Twin Falls ROR 10.3 10.7 5.5 6.4 17.9 18.6 10.5 - - 6.6 4.5 6.0 8.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.1 13.1 12.3 12.8 16.9 15.5 12.4 7.1 11.8 13.9 11.9 11.9 12.7
Upper Salmon 3&4 ROR 12.4 12.4 11.7 12.1 15.7 14.4 11.8 7.3 11.3 13.1 11.4 11.4 12.1
HCC Total 544.2 668.6 577.7 711.0 885.0 588.2 509.9 354.6 373.9 401.3 344.4 435.4 532.8
ROR Total 201.5 205.1 192.5 226.3 310.8 317.0 270.8 198.6 206.3 209.2 176.2 180.6 224.6
Total 745.7 873.7 770.2 937.3 1,195.8 905.2 780.7 553.2 580.1 610.5 520.6 616.0 757.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032 aMW
Brownlee HCC* 240.7 296.2 245.9 312.6 392.1 256.8 225.3 150.1 155.7 169.9 148.2 193.1 232.2
Oxbow HCC 101.3 124.6 108.5 131.2 162.2 108.1 95.3 68.4 71.9 78.0 65.6 80.7 99.6
Hells Canyon HCC 200.8 246.1 221.6 265.5 329.2 221.4 188.0 134.6 141.4 153.5 130.5 160.2 199.4
1000 Springs ROR**- - 9.9 33.1 71.6 88.5 84.6 61.4 34.5 14.1 - - 33.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 35.4 35.4 33.9 35.5 40.6 36.9 32.9 25.2 32.9 36.4 33.4 33.2 34.3
C .J. Strike ROR 45.7 47.1 44.6 47.6 47.4 42.4 33.0 27.1 38.8 45.9 43.3 43.2 42.2
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.7 21.6 20.4 20.9 26.4 24.7 20.8 13.6 19.9 23.0 20.3 20.3 21.1
Milner ROR 7.3 7.8 - - 15.0 14.5 6.2 - - - - 1.6 4.4
Shoshone Falls ROR 12.0 12.0 8.9 9.4 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.6 10.0
Swan Falls ROR 15.3 15.4 15.2 16.3 15.9 14.5 11.8 9.7 13.4 15.2 14.7 14.7 14.3
Twin Falls ROR 10.3 10.6 5.3 5.7 17.9 18.3 10.5 - - 6.6 4.5 5.9 8.0
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.9 13.0 12.2 12.6 16.8 15.3 12.3 7.0 11.6 13.8 11.8 11.8 12.6
Upper Salmon 3&4 ROR 12.3 12.3 11.6 12.0 15.6 14.3 11.7 7.2 11.1 13.0 11.3 11.3 12.0
HCC Total 542.8 666.9 576.0 709.3 883.4 586.3 508.6 353.1 369.0 401.4 344.3 434.0 531.3
ROR Total 200.5 203.7 191.0 221.8 309.9 315.6 270.1 197.8 204.9 208.3 175.3 179.4 223.2
Total 743.3 870.6 767.0 931.1 1,193.3 901.9 778.7 550.9 573.8 609.7 519.6 613.4 754.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 154 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033 aMW
Brownlee HCC* 240.1 295.5 243.7 311.7 391.6 256.0 224.7 149.5 153.8 169.7 148.7 192.4 231.4
Oxbow HCC 101.1 124.3 107.6 130.8 162.0 107.7 95.0 68.1 70.9 77.8 65.7 80.4 99.3
Hells Canyon HCC 200.3 245.5 219.8 264.8 328.7 220.7 187.5 134.1 139.5 153.2 130.8 159.6 198.7
1000 Springs ROR**- - 9.0 33.1 71.6 88.5 84.7 61.4 34.5 14.0 - - 33.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 35.3 35.2 33.8 35.3 40.5 36.7 32.8 25.0 32.6 36.2 33.2 33.0 34.1
C .J. Strike ROR 45.0 46.6 44.4 47.4 47.2 42.3 32.8 26.9 38.5 45.7 43.2 42.6 41.9
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.6 21.5 20.3 20.7 26.3 24.5 20.6 13.4 19.7 22.8 20.2 20.1 21.0
Milner ROR 7.3 7.8 - - 14.3 14.2 6.2 - - - - 1.6 4.3
Shoshone Falls ROR 12.0 12.0 8.6 8.8 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.6 9.9
Swan Falls ROR 15.2 15.3 15.1 16.3 15.8 14.4 11.7 9.6 13.3 15.4 14.6 14.5 14.3
Twin Falls ROR 10.3 10.6 4.8 5.2 17.7 18.2 10.5 - - 6.6 4.5 5.9 7.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.8 12.9 12.1 12.5 16.8 15.2 12.2 6.9 11.4 13.7 11.6 11.7 12.5
Upper Salmon 3&4 ROR 12.2 12.2 11.6 11.9 15.6 14.2 11.6 7.1 11.0 12.9 11.2 11.2 11.9
HCC Total 541.5 665.3 571.1 707.3 882.2 584.4 507.2 351.7 364.2 400.7 345.2 432.4 529.4
ROR Total 199.3 202.6 188.7 219.9 308.5 314.4 269.4 196.9 203.7 207.6 174.5 178.0 222.0
Total 740.8 867.9 759.8 927.2 1,190.7 898.8 776.6 548.6 567.8 608.3 519.7 610.4 751.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70 Percentile Water, 70 Percentile Load
Resource Type 1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034 aMW
Brownlee HCC* 240.1 294.7 242.8 310.9 391.1 255.1 224.1 148.9 151.9 169.8 148.4 192.2 230.8
Oxbow HCC 101.1 123.9 107.1 130.5 161.8 107.3 94.8 67.8 69.9 77.8 65.6 80.3 99.0
Hells Canyon HCC 200.3 244.9 219.0 264.1 328.3 220.0 187.1 133.5 137.6 153.1 130.5 159.4 198.1
1000 Springs ROR**- - 8.6 33.1 71.6 88.3 84.6 61.3 34.5 14.0 - - 33.0
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.9 35.0 33.6 35.2 40.4 36.5 32.6 24.8 32.4 36.0 32.8 32.8 33.9
C .J. Strike ROR 44.1 45.2 44.2 47.2 47.1 42.0 32.6 26.7 38.2 45.5 43.0 42.2 41.5
Cascade ROR 1.5 1.4 1.3 1.2 2.1 7.0 7.4 12.1 7.4 1.5 1.3 1.4 3.8
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.4 21.3 20.1 20.5 26.2 24.3 20.5 13.2 19.5 22.7 19.9 19.9 20.8
Milner ROR 7.3 7.5 - - 14.3 14.2 6.2 - - - - 1.6 4.3
Shoshone Falls ROR 12.0 12.0 8.5 8.6 12.0 12.0 12.0 6.9 6.7 10.5 8.2 9.6 9.9
Swan Falls ROR 15.0 15.3 15.0 16.2 15.7 14.4 11.6 9.5 13.2 15.3 14.6 14.4 14.2
Twin Falls ROR 10.3 10.5 4.7 4.8 17.7 18.2 10.5 - - 6.6 4.5 5.9 7.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.7 12.8 12.0 12.3 16.7 15.0 12.1 6.7 11.3 13.5 11.4 11.5 12.3
Upper Salmon 3&4 ROR 12.1 12.1 11.5 11.8 15.5 14.1 11.5 7.0 10.8 12.8 11.0 11.0 11.8
HCC Total 541.5 663.5 568.9 705.5 881.1 582.4 506.0 350.2 359.4 400.7 344.5 431.9 528.0
ROR Total 197.4 200.2 187.2 218.4 307.9 313.2 268.5 195.8 202.6 206.7 173.2 176.7 220.7
Total 738.9 863.7 756.1 923.9 1,189.0 895.6 774.5 546.0 561.9 607.4 517.7 608.6 748.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 155
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015 aMW
Brownlee HCC* 211.6 197.2 238.9 253.6 272.2 204.3 218.2 144.1 157.4 153.8 149.0 191.1 199.3
Oxbow HCC 88.6 82.8 99.9 105.6 112.7 84.2 91.9 65.5 73.1 70.5 65.7 79.6 85.0
Hells Canyon HCC 175.1 164.8 202.4 214.2 231.3 169.8 180.6 128.8 143.1 139.2 130.4 157.4 169.8
1000 Springs ROR**0.0 0.0 0.0 29.8 70.5 86.4 85.4 56.2 28.0 9.4 0.0 0.0 30.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.7 35.0 33.4 32.5 38.0 36.7 33.5 26.6 35.2 37.7 35.6 35.4 34.5
C .J. Strike ROR 44.1 43.7 43.5 41.2 42.5 39.4 31.3 29.0 39.0 44.9 44.5 44.0 40.6
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.3 22.6 20.6 20.0 25.5 24.4 21.8 15.0 22.0 24.1 22.9 22.7 22.0
Milner ROR 6.0 6.1 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 4.9 4.1
Shoshone Falls ROR 12.0 12.0 7.6 4.5 12.0 12.0 12.0 6.5 6.5 9.2 10.7 12.0 9.8
Swan Falls ROR 14.9 14.8 14.8 14.2 14.7 14.0 11.4 10.2 13.8 15.2 15.2 15.0 14.0
Twin Falls ROR 9.3 9.3 4.0 0.0 15.9 16.4 10.1 0.0 0.0 5.5 6.8 8.9 7.2
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.4 13.8 12.3 11.9 16.1 15.1 13.1 8.1 13.2 14.7 13.8 13.7 13.3
Upper Salmon 3&4 ROR 12.7 13.0 11.7 11.4 15.0 14.1 12.4 8.1 12.5 13.7 13.0 12.9 12.5
HCC Total 475.3 444.8 541.2 573.4 616.1 458.3 490.7 338.4 373.6 363.5 345.1 428.1 454.0
ROR Total 196.9 198.8 176.9 194.3 293.2 302.6 271.1 197.6 205.2 204.1 190.3 197.2 219.0
Total 672.2 643.6 718.1 767.7 909.3 760.9 761.8 536.0 578.8 567.6 535.4 625.3 673.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2016 2/2016 3/2016 4/2016 5/2016 6/2016 7/2016 8/2016 9/2016 10/2016 11/2016 12/2016 aMW
Brownlee HCC* 211.3 200.1 238.7 253.8 275.8 203.8 218.0 143.7 156.5 154.1 149.1 190.8 199.6
Oxbow HCC 88.4 84.1 99.8 105.7 114.2 84.0 91.8 65.3 72.7 70.7 65.7 79.5 85.2
Hells Canyon HCC 174.8 167.2 202.3 214.4 234.2 169.5 180.4 128.4 142.3 139.4 130.5 157.1 170.0
1000 Springs ROR**0.0 0.0 0.0 29.7 70.5 86.7 85.6 56.9 28.9 9.3 0.0 0.0 30.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.7 35.0 33.4 32.8 38.0 36.6 33.4 26.5 35.0 37.7 35.4 35.3 34.5
C .J. Strike ROR 44.0 43.5 43.5 41.1 42.5 39.3 31.2 28.9 38.8 44.9 44.4 43.9 40.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.2 22.5 20.5 19.9 25.4 24.3 21.8 14.9 21.9 24.1 22.8 22.6 21.9
Milner ROR 6.1 7.1 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 4.9 4.2
Shoshone Falls ROR 12.0 12.0 7.6 4.5 12.0 12.0 12.0 6.5 6.5 9.8 11.1 12.0 9.8
Swan Falls ROR 14.9 14.8 14.8 14.2 14.8 14.0 11.4 10.2 13.8 15.2 15.2 15.0 14.0
Twin Falls ROR 9.3 9.9 4.0 0.0 15.9 16.4 10.1 0.0 0.0 6.0 7.2 8.9 7.3
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.3 13.7 12.3 11.9 16.1 15.0 13.1 8.0 13.1 14.6 13.7 13.6 13.2
Upper Salmon 3&4 ROR 12.6 13.0 11.7 11.4 15.0 14.1 12.4 8.1 12.4 13.7 12.9 12.9 12.5
HCC Total 474.5 451.4 540.8 573.9 624.1 457.3 490.2 337.4 371.4 364.2 345.3 427.4 454.8
ROR Total 196.6 200.0 176.8 194.3 293.2 302.5 271.1 197.9 205.4 205.0 190.5 196.8 219.2
Total 671.1 651.4 717.6 768.2 917.3 759.8 761.3 535.3 576.7 569.2 535.8 624.2 674.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 156 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2017 2/2017 3/2017 4/2017 5/2017 6/2017 7/2017 8/2017 9/2017 10/2017 11/2017 12/2017 aMW
Brownlee HCC* 210.7 201.0 236.8 257.8 280.9 204.0 218.4 143.7 155.6 154.3 149.6 189.2 200.2
Oxbow HCC 88.2 84.4 99.0 107.3 114.6 84.1 92.0 65.3 72.2 70.6 65.9 78.8 85.2
Hells Canyon HCC 174.3 167.9 200.7 217.6 234.1 169.6 180.7 128.4 141.3 139.3 130.8 155.9 170.0
1000 Springs ROR**0.0 0.0 0.0 29.9 70.7 86.7 85.7 57.1 30.1 9.4 0.0 0.0 30.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.3 34.7 33.2 33.2 38.3 36.6 33.4 26.5 34.9 37.6 34.8 34.7 34.4
C .J. Strike ROR 43.7 43.3 43.5 41.4 43.5 39.6 31.4 29.0 38.8 44.9 44.1 43.2 40.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.1 22.3 20.4 20.0 25.5 24.3 21.8 14.9 21.9 24.1 22.3 22.1 21.8
Milner ROR 5.0 7.0 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 3.8 4.0
Shoshone Falls ROR 12.0 12.0 7.3 4.5 12.0 12.0 12.0 6.5 6.5 10.0 9.8 12.0 9.7
Swan Falls ROR 14.8 14.7 14.8 14.2 15.1 14.1 11.5 10.2 13.8 15.2 15.0 14.8 14.0
Twin Falls ROR 8.7 9.8 3.8 0.0 15.9 16.4 10.1 0.0 0.0 6.2 6.1 8.3 7.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.2 13.5 12.2 11.9 16.2 15.0 13.1 8.0 13.1 14.6 13.3 13.2 13.1
Upper Salmon 3&4 ROR 12.5 12.8 11.6 11.4 15.0 14.1 12.4 8.1 12.4 13.7 12.5 12.5 12.4
HCC Total 473.2 453.3 536.5 582.7 629.5 457.7 491.1 337.4 369.0 364.2 346.3 423.9 455.4
ROR Total 193.8 198.6 175.8 195.3 295.2 302.9 271.5 198.2 206.5 205.4 185.7 192.3 218.4
Total 667.0 651.9 712.3 778.0 924.7 760.6 762.6 535.6 575.5 569.6 532.0 616.2 673.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2018 2/2018 3/2018 4/2018 5/2018 6/2018 7/2018 8/2018 9/2018 10/2018 11/2018 12/2018 aMW
Brownlee HCC* 209.6 202.7 236.0 258.1 281.9 203.7 218.1 143.4 154.5 154.1 149.5 188.5 200.0
Oxbow HCC 87.7 85.2 98.7 107.4 115.0 84.0 91.9 65.1 71.6 70.5 65.8 78.5 85.1
Hells Canyon HCC 173.4 169.3 200.0 217.8 234.9 169.4 180.5 128.1 140.3 139.1 130.7 155.3 169.9
1000 Springs ROR**0.0 0.0 0.0 29.8 70.8 86.8 85.7 57.2 30.4 10.3 0.0 0.0 30.9
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.2 34.6 33.3 33.0 38.3 36.5 33.4 26.4 34.8 37.6 34.8 34.5 34.3
C .J. Strike ROR 43.6 43.2 43.5 41.1 43.6 39.6 31.3 28.9 38.6 44.8 44.0 42.8 40.4
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.1 22.2 20.4 20.0 25.5 24.3 21.7 14.8 21.7 24.0 22.2 21.8 21.7
Milner ROR 5.0 7.0 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 3.2 3.9
Shoshone Falls ROR 12.0 12.0 7.3 4.5 12.0 12.0 12.0 6.5 6.5 10.0 9.8 11.8 9.7
Swan Falls ROR 14.8 14.7 14.8 14.4 15.1 14.0 11.4 10.1 13.7 15.1 15.0 14.7 14.0
Twin Falls ROR 8.7 9.8 3.8 0.0 16.0 16.8 10.1 0.0 0.0 6.2 6.1 7.8 7.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.3 13.5 12.2 11.9 16.2 15.0 13.0 8.0 13.0 14.6 13.2 13.0 13.1
Upper Salmon 3&4 ROR 12.5 12.7 11.6 11.4 15.0 14.0 12.4 8.0 12.3 13.7 12.5 12.3 12.4
HCC Total 470.7 457.2 534.7 583.3 631.8 457.1 490.5 336.6 366.3 363.7 346.0 422.3 455.0
ROR Total 193.7 198.2 175.9 194.9 295.5 303.1 271.1 197.8 206.0 206.0 185.4 189.6 218.1
Total 664.4 655.4 710.6 778.2 927.2 760.2 761.6 534.4 572.3 569.7 531.4 611.9 673.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 157
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2019 2/2019 3/2019 4/2019 5/2019 6/2019 7/2019 8/2019 9/2019 10/2019 11/2019 12/2019 aMW
Brownlee HCC* 209.6 205.5 232.5 257.6 283.9 204.5 218.9 143.3 153.6 154.6 149.9 180.0 199.5
Oxbow HCC 87.7 86.4 97.2 107.2 115.8 84.2 92.2 65.1 71.1 70.6 65.9 78.0 85.1
Hells Canyon HCC 173.4 171.6 197.2 217.4 236.5 170.0 181.1 128.0 139.3 139.3 130.9 153.8 169.9
1000 Springs ROR**0.0 0.0 8.0 29.6 70.6 86.9 85.6 57.3 30.6 11.2 0.0 0.0 31.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 34.1 34.6 33.4 32.8 38.6 36.7 33.3 26.5 34.7 37.6 34.4 33.9 34.2
C .J. Strike ROR 43.4 43.2 43.8 41.2 43.9 39.8 31.6 28.9 38.6 44.9 43.6 42.2 40.4
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.1 22.2 20.5 20.1 25.7 24.4 21.7 14.9 21.5 24.1 21.5 21.3 21.7
Milner ROR 5.0 6.8 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.6
Shoshone Falls ROR 12.0 12.0 7.3 4.0 12.0 12.0 12.0 6.5 6.5 10.0 8.2 9.6 9.3
Swan Falls ROR 14.8 14.7 14.9 14.3 15.2 14.1 11.5 10.2 13.7 15.2 14.8 14.4 14.0
Twin Falls ROR 8.6 9.6 3.8 0.0 15.9 16.4 10.1 0.0 0.0 6.2 4.5 5.9 6.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.2 13.5 12.3 12.0 16.3 15.1 13.0 8.0 12.8 14.6 12.7 12.6 13.0
Upper Salmon 3&4 ROR 12.5 12.7 11.7 11.5 15.2 14.1 12.4 8.1 12.2 13.7 12.0 12.0 12.3
HCC Total 470.7 463.5 526.9 582.2 636.2 458.7 492.2 336.4 364.0 364.5 346.7 411.8 454.5
ROR Total 193.2 197.8 184.7 194.3 296.4 303.6 271.3 198.3 205.6 207.2 179.5 179.6 217.6
Total 663.9 661.3 711.6 776.5 932.6 762.3 763.5 534.7 569.6 571.7 526.2 591.4 672.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2020 2/2020 3/2020 4/2020 5/2020 6/2020 7/2020 8/2020 9/2020 10/2020 11/2020 12/2020 aMW
Brownlee HCC* 208.9 200.8 232.5 256.6 283.2 203.7 218.3 142.6 151.9 154.7 149.4 180.0 198.6
Oxbow HCC 87.4 84.4 97.2 106.8 115.6 83.9 92.0 64.8 70.2 70.6 65.7 77.9 84.7
Hells Canyon HCC 172.8 167.8 197.2 216.7 235.9 169.4 180.6 127.4 137.6 139.2 130.4 153.8 169.1
1000 Springs ROR**0.0 0.0 8.0 29.6 70.6 86.8 85.6 57.0 30.2 11.0 0.0 0.0 31.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.9 34.4 33.4 32.6 38.4 36.5 33.1 26.3 34.4 37.4 34.3 33.8 34.0
C .J. Strike ROR 43.2 43.2 43.6 41.1 43.2 39.5 31.4 28.7 38.4 44.8 43.4 42.3 40.2
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 22.0 22.1 20.4 20.0 25.6 24.2 21.6 14.8 21.2 23.9 21.4 21.3 21.5
Milner ROR 5.0 6.8 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.6
Shoshone Falls ROR 12.0 12.0 7.3 4.0 12.0 12.0 12.0 6.5 6.5 10.0 8.2 9.6 9.3
Swan Falls ROR 14.7 14.7 14.8 14.3 14.9 14.0 11.5 10.1 13.7 15.1 14.8 14.5 13.9
Twin Falls ROR 8.6 9.6 3.8 0.0 15.9 16.4 10.1 0.0 0.0 6.2 4.5 5.9 6.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 13.2 13.4 12.2 11.9 16.2 14.9 12.9 7.9 12.6 14.5 12.6 12.6 12.9
Upper Salmon 3&4 ROR 12.5 12.7 11.7 11.4 15.1 14.0 12.3 8.0 12.0 13.6 12.0 11.9 12.3
HCC Total 469.1 453.0 526.9 580.1 634.6 457.0 490.9 334.8 359.7 364.5 345.5 411.7 452.3
ROR Total 192.6 197.4 184.2 193.7 294.9 302.4 270.6 197.2 204.0 206.2 179.0 179.6 216.8
Total 661.7 650.4 711.1 773.8 929.5 759.4 761.5 532.0 563.6 570.7 524.5 591.3 669.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 158 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2021 2/2021 3/2021 4/2021 5/2021 6/2021 7/2021 8/2021 9/2021 10/2021 11/2021 12/2021 aMW
Brownlee HCC* 208.3 196.1 230.3 256.2 282.5 202.9 217.6 141.9 149.7 154.7 149.5 179.7 197.4
Oxbow HCC 87.1 82.4 96.3 106.6 115.3 83.6 91.7 64.4 69.0 70.4 65.7 77.8 84.2
Hells Canyon HCC 172.3 163.9 195.5 216.3 235.3 168.8 180.1 126.8 135.4 139.0 130.4 153.5 168.1
1000 Springs ROR**0.0 0.0 8.0 29.6 70.6 86.6 85.5 56.9 29.8 10.9 0.0 0.0 31.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.8 34.3 33.2 32.5 38.3 36.3 33.0 26.1 34.2 37.2 34.2 33.6 33.9
C .J. Strike ROR 42.8 42.8 43.5 41.0 43.0 39.2 31.1 28.5 38.3 44.6 43.3 42.0 40.0
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.6 21.9 20.3 19.9 25.5 24.0 21.5 14.6 21.0 23.8 21.2 21.1 21.4
Milner ROR 5.0 6.1 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.6
Shoshone Falls ROR 12.0 12.0 7.3 4.0 12.0 12.0 12.0 6.5 6.5 9.8 8.2 9.6 9.3
Swan Falls ROR 14.7 14.6 14.8 14.2 14.9 13.9 11.4 10.0 13.6 15.1 14.7 14.4 13.9
Twin Falls ROR 8.6 9.4 3.8 0.0 15.9 16.4 10.1 0.0 0.0 6.0 4.5 5.9 6.7
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.9 13.2 12.1 11.9 16.2 14.8 12.9 7.8 12.4 14.4 12.5 12.4 12.8
Upper Salmon 3&4 ROR 12.2 12.5 11.6 11.3 15.0 13.9 12.2 7.9 11.8 13.5 11.9 11.8 12.1
HCC Total 467.7 442.4 522.1 579.1 633.0 455.3 489.4 333.1 354.0 364.1 345.6 411.0 449.7
ROR Total 191.1 195.3 183.6 193.2 294.4 301.2 269.8 196.2 202.6 205.0 178.3 178.5 215.8
Total 658.8 637.7 705.7 772.3 927.4 756.5 759.2 529.3 556.6 569.1 523.9 589.5 665.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2022 2/2022 3/2022 4/2022 5/2022 6/2022 7/2022 8/2022 9/2022 10/2022 11/2022 12/2022 aMW
Brownlee HCC* 207.6 194.1 229.4 255.7 281.8 202.5 217.0 141.2 147.4 154.8 149.6 179.3 196.7
Oxbow HCC 86.9 81.5 95.9 106.4 115.0 83.4 91.4 64.1 67.9 70.4 65.7 77.6 83.8
Hells Canyon HCC 171.8 162.3 194.7 215.9 234.8 168.4 179.5 126.2 133.2 138.8 130.5 153.2 167.4
1000 Springs ROR**0.0 0.0 8.0 29.5 70.6 86.5 85.5 56.5 29.6 10.9 0.0 0.0 31.4
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.6 34.1 33.0 32.5 38.2 36.1 32.9 25.9 33.9 37.0 34.0 33.4 33.7
C .J. Strike ROR 42.5 42.5 42.5 40.9 42.8 38.9 30.9 28.2 38.1 44.3 43.1 41.8 39.7
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.4 21.7 20.2 19.8 25.4 23.9 21.4 14.4 20.8 23.7 21.1 20.9 21.2
Milner ROR 5.0 5.9 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.6
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 9.6 8.2 9.6 9.3
Swan Falls ROR 14.6 14.5 14.5 14.1 14.8 13.8 11.2 9.9 13.6 15.0 14.6 14.3 13.7
Twin Falls ROR 8.6 9.3 3.8 0.0 15.9 16.4 10.1 0.0 0.0 5.8 4.5 5.9 6.7
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.7 13.1 12.1 11.8 16.1 14.7 12.8 7.6 12.2 14.3 12.3 12.3 12.7
Upper Salmon 3&4 ROR 12.1 12.4 11.5 11.3 15.0 13.8 12.1 7.8 11.7 13.4 11.8 11.7 12.1
HCC Total 466.3 437.9 520.0 578.0 631.5 454.3 487.9 331.5 348.4 364.0 345.8 410.1 448.0
ROR Total 190.0 194.0 181.9 192.6 293.8 300.2 269.0 194.7 201.4 203.7 177.4 177.6 214.7
Total 656.3 631.9 701.9 770.6 925.3 754.5 756.9 526.2 549.8 567.7 523.2 587.7 662.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 159
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2023 2/2023 3/2023 4/2023 5/2023 6/2023 7/2023 8/2023 9/2023 10/2023 11/2023 12/2023 aMW
Brownlee HCC* 206.9 193.5 228.5 255.3 281.2 202.0 216.4 140.6 145.3 154.5 149.9 178.7 196.1
Oxbow HCC 86.6 81.3 95.6 106.3 114.7 83.2 91.1 63.8 66.7 70.1 65.8 77.3 83.5
Hells Canyon HCC 171.2 161.8 194.0 215.6 234.3 168.0 179.0 125.6 131.0 138.4 130.7 152.6 166.8
1000 Springs ROR**0.0 0.0 8.0 29.6 70.5 86.5 85.5 56.2 29.0 10.6 0.0 0.0 31.3
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.4 33.9 32.9 32.4 38.1 35.9 32.8 25.7 33.7 36.8 33.8 33.2 33.6
C .J. Strike ROR 42.3 42.3 42.2 40.9 42.7 38.5 30.7 28.0 38.0 44.1 42.8 41.5 39.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.3 21.5 20.1 19.7 25.3 23.7 21.2 14.3 20.6 23.4 20.9 20.8 21.1
Milner ROR 5.0 5.4 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.5
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.8 8.2 9.6 9.2
Swan Falls ROR 14.5 14.4 14.4 14.1 14.8 13.7 11.2 9.9 13.5 14.9 14.5 14.2 13.7
Twin Falls ROR 8.6 8.9 3.8 0.0 15.9 16.4 10.1 0.0 0.0 5.2 4.5 5.9 6.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.6 13.0 12.0 11.7 16.0 14.6 12.6 7.5 12.1 14.1 12.2 12.2 12.6
Upper Salmon 3&4 ROR 12.0 12.3 11.5 11.2 14.9 13.7 12.0 7.7 11.5 13.3 11.6 11.6 11.9
HCC Total 464.7 436.6 518.1 577.2 630.1 453.2 486.5 330.0 342.9 363.0 346.4 408.6 446.4
ROR Total 189.2 192.2 181.2 192.3 293.2 299.1 268.2 193.7 199.9 200.9 176.3 176.7 213.6
Total 653.9 628.8 699.3 769.5 923.3 752.3 754.7 523.7 542.8 563.9 522.7 585.3 660.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2024 2/2024 3/2024 4/2024 5/2024 6/2024 7/2024 8/2024 9/2024 10/2024 11/2024 12/2024 aMW
Brownlee HCC* 206.3 192.8 227.9 254.8 280.4 201.6 215.5 139.9 143.7 154.5 149.7 179.1 195.5
Oxbow HCC 86.3 81.0 95.3 106.1 114.4 83.1 90.8 63.5 65.9 70.1 65.7 77.5 83.3
Hells Canyon HCC 170.7 161.2 193.5 215.2 233.7 167.7 178.4 125.0 129.5 138.4 130.5 153.0 166.4
1000 Springs ROR**0.0 0.0 8.0 29.6 70.2 86.5 85.6 56.2 28.5 10.3 0.0 0.0 31.2
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.3 33.8 32.8 32.4 37.9 35.7 32.6 25.5 33.4 36.5 33.6 33.0 33.4
C .J. Strike ROR 42.0 41.9 42.0 40.7 42.5 38.3 30.5 27.7 37.7 43.8 42.5 41.2 39.2
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.1 21.3 20.1 19.6 25.1 23.5 21.0 14.1 20.3 23.2 20.7 20.5 20.9
Milner ROR 4.9 6.0 0.0 0.0 12.8 12.7 6.2 0.0 0.0 0.0 0.0 0.0 3.6
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.8 8.2 9.6 9.2
Swan Falls ROR 14.4 14.4 14.3 14.0 14.8 13.6 11.1 9.8 13.4 14.8 14.4 14.1 13.6
Twin Falls ROR 8.6 9.2 3.8 0.0 15.9 16.4 10.1 0.0 0.0 5.2 4.5 5.9 6.6
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.5 12.8 12.0 11.6 15.9 14.4 12.5 7.4 11.9 13.9 12.1 12.0 12.4
Upper Salmon 3&4 ROR 11.9 12.2 11.4 11.1 14.8 13.5 11.9 7.6 11.4 13.1 11.5 11.5 11.8
HCC Total 463.3 435.0 516.7 576.1 628.5 452.4 484.7 328.4 339.0 363.0 345.9 409.6 445.2
ROR Total 188.2 192.1 180.7 191.7 292.1 298.0 267.4 192.7 198.1 199.3 175.3 175.5 212.6
Total 651.5 627.1 697.4 767.8 920.6 750.4 752.1 521.1 537.1 562.3 521.2 585.1 657.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 160 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2025 2/2025 3/2025 4/2025 5/2025 6/2025 7/2025 8/2025 9/2025 10/2025 11/2025 12/2025 aMW
Brownlee HCC* 204.8 192.1 227.4 254.4 275.8 201.3 215.0 139.3 142.1 154.1 150.2 178.5 194.6
Oxbow HCC 85.7 80.7 95.1 105.9 114.2 82.9 90.6 63.2 65.1 69.8 65.9 77.3 83.0
Hells Canyon HCC 169.5 160.6 193.1 214.8 234.2 167.5 177.9 124.4 127.9 137.8 130.9 152.5 165.9
1000 Springs ROR**0.0 0.0 8.0 29.5 69.8 85.9 85.6 56.2 28.3 10.5 0.0 0.0 31.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.2 33.7 32.7 32.3 37.3 35.4 32.4 25.3 33.1 36.4 33.4 32.8 33.2
C .J. Strike ROR 41.7 41.8 42.0 40.6 42.0 37.3 30.4 27.5 37.4 43.5 42.3 41.0 39.0
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 21.0 21.2 20.0 19.5 24.9 23.3 20.9 13.9 20.1 23.0 20.5 20.4 20.7
Milner ROR 4.8 6.0 0.0 0.0 11.3 11.2 6.2 0.0 0.0 0.0 0.0 0.0 3.3
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.8 8.2 9.6 9.2
Swan Falls ROR 14.4 14.3 14.3 14.0 14.7 13.3 11.0 9.7 13.3 14.8 14.4 14.1 13.5
Twin Falls ROR 8.5 9.2 3.8 0.0 14.0 15.0 10.1 0.0 0.0 5.2 4.5 5.9 6.4
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.4 12.7 11.9 11.5 15.7 14.2 12.4 7.3 11.7 13.8 11.9 11.9 12.3
Upper Salmon 3&4 ROR 11.8 12.1 11.4 11.1 14.6 13.4 11.8 7.5 11.2 13.0 11.4 11.4 11.7
HCC Total 460.0 433.4 515.6 575.1 624.1 451.7 483.5 326.9 335.0 361.7 347.0 408.3 443.5
ROR Total 187.3 191.5 180.4 191.2 286.5 292.4 266.7 191.8 196.6 198.7 174.4 174.8 211.0
Total 647.3 624.9 696.0 766.3 910.5 744.1 750.2 518.7 531.6 560.4 521.4 583.1 654.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2026 2/2026 3/2026 4/2026 5/2026 6/2026 7/2026 8/2026 9/2026 10/2026 11/2026 12/2026 aMW
Brownlee HCC* 203.8 191.5 226.9 254.0 275.2 201.0 214.3 138.5 140.0 154.2 150.2 177.9 194.0
Oxbow HCC 85.3 80.4 94.9 105.7 113.9 82.8 90.3 62.9 64.1 69.8 65.9 77.0 82.7
Hells Canyon HCC 168.7 160.1 192.6 214.5 233.7 167.2 177.4 123.8 125.9 137.8 130.8 152.0 165.4
1000 Springs ROR**0.0 0.0 7.9 29.4 69.6 85.5 85.5 56.2 28.2 10.4 0.0 0.0 31.1
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.1 33.5 32.6 32.3 37.1 35.1 32.3 25.1 32.8 36.2 33.2 32.8 33.0
C .J. Strike ROR 41.5 41.7 41.8 40.4 41.8 36.5 30.4 27.3 37.1 43.3 42.0 40.8 38.7
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.8 21.0 19.9 19.3 24.3 23.1 20.7 13.8 19.9 22.9 20.4 20.2 20.5
Milner ROR 5.0 6.0 0.0 0.0 10.5 10.4 6.2 0.0 0.0 0.0 0.0 0.0 3.2
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.8 8.2 9.6 9.2
Swan Falls ROR 14.2 14.3 14.3 13.9 14.7 13.1 11.0 9.7 13.2 14.8 14.3 14.1 13.5
Twin Falls ROR 8.6 9.2 3.8 0.0 13.3 14.3 10.1 0.0 0.0 5.2 4.5 5.9 6.2
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.3 12.6 11.8 11.4 15.3 14.1 12.3 7.2 11.5 13.7 11.8 11.8 12.2
Upper Salmon 3&4 ROR 11.7 12.0 11.3 11.0 14.3 13.3 11.7 7.4 11.1 12.9 11.3 11.3 11.6
HCC Total 457.8 432.0 514.4 574.2 622.7 451.0 482.0 325.2 330.0 361.8 346.9 406.9 442.1
ROR Total 186.7 190.8 179.7 190.4 283.1 288.8 266.1 191.1 195.3 197.9 173.5 174.2 209.8
Total 644.5 622.8 694.1 764.6 905.8 739.8 748.1 516.3 525.2 559.7 520.4 581.1 651.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 161
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2027 2/2027 3/2027 4/2027 5/2027 6/2027 7/2027 8/2027 9/2027 10/2027 11/2027 12/2027 aMW
Brownlee HCC* 203.1 190.1 225.7 253.5 274.6 200.7 213.7 137.8 138.1 154.3 149.9 177.6 193.3
Oxbow HCC 85.0 79.9 94.4 105.5 113.7 82.7 90.0 62.5 63.0 69.7 65.7 76.8 82.4
Hells Canyon HCC 168.1 159.0 191.7 214.1 233.2 167.0 176.9 123.1 124.0 137.7 130.5 151.7 164.7
1000 Springs ROR**0.0 0.0 7.9 29.4 69.4 85.6 85.5 56.2 27.8 10.2 0.0 0.0 31.0
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 33.0 33.3 32.5 32.2 37.0 34.8 32.0 24.9 32.5 36.0 33.1 32.6 32.8
C .J. Strike ROR 41.2 41.3 42.0 40.2 41.7 36.2 30.3 27.0 36.8 43.1 41.7 40.4 38.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.7 20.8 19.9 19.2 24.2 23.1 20.5 13.6 19.6 22.7 20.2 20.1 20.4
Milner ROR 5.0 5.1 0.0 0.0 10.5 10.4 6.2 0.0 0.0 0.0 0.0 0.0 3.1
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.8 8.2 9.6 9.2
Swan Falls ROR 14.2 14.1 14.3 13.8 14.7 13.0 10.9 9.6 13.1 14.8 14.2 14.0 13.4
Twin Falls ROR 8.6 8.5 3.8 0.0 13.3 14.3 10.1 0.0 0.0 5.2 4.5 5.9 6.2
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.2 12.4 11.8 11.3 15.2 14.1 12.1 7.0 11.4 13.6 11.7 11.7 12.0
Upper Salmon 3&4 ROR 11.6 11.8 11.3 10.9 14.2 13.2 11.6 7.2 10.9 12.8 11.2 11.2 11.5
HCC Total 456.2 429.0 511.8 573.1 621.5 450.4 480.6 323.4 325.0 361.7 346.1 406.1 440.4
ROR Total 186.0 187.8 179.8 189.7 282.4 288.1 265.1 189.9 193.6 196.9 172.6 173.2 208.8
Total 642.2 616.8 691.6 762.8 903.9 738.5 745.7 513.3 518.6 558.6 518.7 579.3 649.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2028 2/2028 3/2028 4/2028 5/2028 6/2028 7/2028 8/2028 9/2028 10/2028 11/2028 12/2028 aMW
Brownlee HCC* 202.5 190.4 224.7 253.1 274.0 200.4 213.3 137.2 135.5 154.2 150.4 176.4 192.7
Oxbow HCC 84.7 80.0 94.0 105.3 113.4 82.6 89.8 62.2 61.7 69.6 65.9 76.3 82.1
Hells Canyon HCC 167.6 159.3 190.9 213.8 232.7 166.7 176.5 122.6 121.5 137.3 130.9 150.7 164.2
1000 Springs ROR**0.0 0.0 7.9 29.4 69.5 85.6 85.6 56.2 27.3 10.4 0.0 0.0 31.0
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.9 33.0 32.4 32.1 37.0 34.6 31.8 24.8 32.2 35.8 32.6 32.4 32.6
C .J. Strike ROR 40.9 41.1 41.8 40.0 41.6 36.0 30.2 26.8 36.4 43.0 41.5 40.2 38.3
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.5 20.7 19.7 19.1 24.1 23.0 20.4 13.5 19.4 22.5 20.0 20.0 20.2
Milner ROR 5.0 5.2 0.0 0.0 10.5 10.4 6.2 0.0 0.0 0.0 0.0 0.0 3.1
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.7 8.2 9.2 9.2
Swan Falls ROR 14.2 14.1 14.3 13.8 14.7 12.9 10.8 9.5 13.0 14.7 14.1 14.0 13.3
Twin Falls ROR 8.5 8.5 3.8 0.0 13.3 14.3 10.1 0.0 0.0 4.8 4.5 5.5 6.1
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.1 12.3 11.6 11.2 15.1 14.0 12.0 6.9 11.2 13.4 11.5 11.6 11.9
Upper Salmon 3&4 ROR 11.5 11.8 11.2 10.8 14.1 13.2 11.5 7.1 10.8 12.7 11.1 11.1 11.4
HCC Total 454.8 429.7 509.6 572.2 620.1 449.7 479.6 322.0 318.7 361.1 347.2 403.4 439.0
ROR Total 185.1 187.2 179.0 189.1 282.1 287.4 264.5 189.2 191.8 195.7 171.3 171.7 207.8
Total 639.9 616.9 688.6 761.3 902.2 737.1 744.1 511.2 510.4 556.8 518.5 575.1 646.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 162 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2029 2/2029 3/2029 4/2029 5/2029 6/2029 7/2029 8/2029 9/2029 10/2029 11/2029 12/2029 aMW
Brownlee HCC* 201.9 189.8 223.8 252.7 273.4 200.1 212.7 136.6 133.5 154.3 150.2 175.6 192.0
Oxbow HCC 84.5 79.7 93.6 105.2 113.2 82.4 89.6 62.0 60.7 69.5 65.7 75.9 81.8
Hells Canyon HCC 167.1 158.7 190.2 213.5 232.3 166.5 176.0 122.0 119.5 137.3 130.6 150.0 163.6
1000 Springs ROR**0.0 0.0 7.8 29.4 69.1 84.8 85.5 56.1 26.6 10.3 0.0 0.0 30.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.9 32.7 32.3 32.0 36.2 34.0 31.7 24.6 32.0 35.6 32.5 32.1 32.4
C .J. Strike ROR 40.9 40.9 41.8 39.8 41.4 35.5 30.1 26.5 36.1 42.9 41.2 40.0 38.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.4 20.6 19.6 19.0 23.6 22.6 20.3 13.3 19.2 22.3 19.9 19.7 20.0
Milner ROR 5.0 5.0 0.0 0.0 9.7 9.6 6.2 0.0 0.0 0.0 0.0 0.0 3.0
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.7 8.2 9.2 9.2
Swan Falls ROR 14.1 14.1 14.3 13.7 14.6 12.5 10.8 9.4 12.9 14.7 14.1 13.9 13.3
Twin Falls ROR 8.5 8.1 3.8 0.0 12.4 13.1 10.1 0.0 0.0 4.8 4.5 5.5 5.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 12.0 12.2 11.6 11.2 14.7 13.7 11.9 6.8 11.0 13.3 11.4 11.3 11.8
Upper Salmon 3&4 ROR 11.4 11.7 11.1 10.8 13.8 12.9 11.4 7.0 10.6 12.6 10.9 10.9 11.3
HCC Total 453.5 428.2 507.6 571.4 618.8 449.0 478.3 320.6 313.7 361.1 346.5 401.5 437.5
ROR Total 184.7 185.8 178.6 188.6 277.7 282.1 263.9 188.1 189.9 194.9 170.5 170.3 206.3
Total 638.2 614.0 686.2 760.0 896.5 731.1 742.2 508.7 503.5 556.0 517.0 571.8 643.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2030 2/2030 3/2030 4/2030 5/2030 6/2030 7/2030 8/2030 9/2030 10/2030 11/2030 12/2030 aMW
Brownlee HCC* 201.5 189.1 223.1 252.2 272.8 199.8 212.1 135.8 131.5 154.5 150.2 175.4 191.5
Oxbow HCC 84.3 79.4 93.3 105.0 112.9 82.3 89.3 61.6 59.7 69.5 65.7 75.9 81.6
Hells Canyon HCC 166.8 158.2 189.5 213.1 231.8 166.3 175.5 121.4 117.6 137.3 130.5 149.8 163.1
1000 Springs ROR**0.0 0.0 7.9 29.4 69.4 85.0 85.5 56.1 26.5 10.2 0.0 0.0 30.8
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.7 32.5 32.2 31.9 36.4 34.2 31.5 24.4 31.7 35.4 32.4 32.0 32.3
C .J. Strike ROR 40.6 40.6 41.5 39.5 41.3 35.2 29.9 26.3 35.8 42.8 41.0 39.7 37.9
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.3 20.3 19.5 18.9 23.6 22.5 20.1 13.1 19.0 22.2 19.7 19.7 19.9
Milner ROR 5.0 4.7 0.0 0.0 9.6 9.5 6.2 0.0 0.0 0.0 0.0 0.0 2.9
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.7 8.2 9.2 9.2
Swan Falls ROR 14.2 14.0 14.2 13.6 14.5 12.8 10.7 9.3 12.8 14.6 14.1 13.8 13.2
Twin Falls ROR 8.5 8.0 3.8 0.0 12.3 13.0 10.1 0.0 0.0 4.8 4.5 5.5 5.9
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 11.8 12.0 11.5 11.1 14.7 13.6 11.8 6.7 10.8 13.2 11.3 11.3 11.7
Upper Salmon 3&4 ROR 11.3 11.5 11.0 10.7 13.8 12.8 11.3 6.9 10.5 12.5 10.9 10.9 11.2
HCC Total 452.6 426.7 505.9 570.3 617.4 448.4 476.9 318.8 308.7 361.3 346.4 401.1 436.2
ROR Total 183.9 184.1 177.9 187.8 277.8 282.0 263.0 187.2 188.6 194.1 169.9 169.8 205.5
Total 636.5 610.8 683.8 758.1 895.2 730.4 739.9 506.0 497.3 555.4 516.3 570.9 641.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2015 Integrated Resource Plan—Appendix C Page 163
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2031 2/2031 3/2031 4/2031 5/2031 6/2031 7/2031 8/2031 9/2031 10/2031 11/2031 12/2031 aMW
Brownlee HCC* 201.2 188.2 222.3 251.8 272.4 199.5 211.4 135.3 129.4 154.1 150.6 174.8 190.9
Oxbow HCC 84.2 79.0 93.0 104.8 112.8 82.2 89.1 61.4 58.6 69.2 65.9 75.6 81.3
Hells Canyon HCC 166.5 157.4 188.9 212.8 231.4 166.0 175.0 120.9 115.6 136.7 130.8 149.3 162.6
1000 Springs ROR**0.0 0.0 7.9 29.4 69.2 85.0 85.6 56.1 26.4 9.4 0.0 0.0 30.7
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.5 32.4 32.1 31.8 36.1 33.7 31.3 24.2 31.4 35.2 32.2 31.7 32.1
C .J. Strike ROR 40.4 40.3 41.3 39.2 41.1 34.9 29.7 26.1 35.4 42.7 40.7 39.2 37.6
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.1 20.1 19.4 18.8 23.5 22.3 19.9 13.0 18.7 22.0 19.6 19.3 19.7
Milner ROR 4.7 4.7 0.0 0.0 9.6 9.5 6.2 0.0 0.0 0.0 0.0 0.0 2.9
Shoshone Falls ROR 12.0 11.9 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.4 8.2 8.9 9.1
Swan Falls ROR 14.1 14.0 14.2 13.6 14.5 12.6 10.7 9.3 12.8 14.5 14.0 13.7 13.2
Twin Falls ROR 8.4 7.9 3.8 0.0 12.3 13.0 10.1 0.0 0.0 4.6 4.5 5.3 5.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 11.7 11.9 11.4 11.0 14.6 13.5 11.7 6.5 10.7 13.0 11.2 11.1 11.5
Upper Salmon 3&4 ROR 11.2 11.4 11.0 10.6 13.7 12.7 11.2 6.8 10.3 12.3 10.8 10.7 11.1
HCC Total 451.9 424.6 504.2 569.4 616.5 447.7 475.5 317.6 303.6 360.0 347.3 399.7 434.8
ROR Total 182.6 183.1 177.4 187.1 276.8 280.6 262.3 186.4 187.2 191.8 169.0 167.6 204.3
Total 634.5 607.7 681.6 756.5 893.3 728.3 737.8 504.0 490.8 551.8 516.3 567.3 639.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2032 2/2032 3/2032 4/2032 5/2032 6/2032 7/2032 8/2032 9/2032 10/2032 11/2032 12/2032 aMW
Brownlee HCC* 200.9 187.5 221.6 251.4 272.0 199.2 210.9 134.7 127.3 154.2 150.7 174.1 190.4
Oxbow HCC 84.0 78.8 92.7 104.6 112.6 82.1 88.8 61.1 57.6 69.2 65.9 75.3 81.1
Hells Canyon HCC 166.2 156.9 188.3 212.4 231.1 165.8 174.5 120.3 113.6 136.6 130.8 148.8 162.1
1000 Springs ROR**0.0 0.0 7.7 29.6 68.6 84.8 85.6 55.7 26.3 9.4 0.0 0.0 30.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.4 32.2 32.0 31.7 35.7 33.3 31.2 24.0 31.1 35.0 32.0 31.5 31.8
C .J. Strike ROR 40.2 40.1 41.2 38.9 41.0 34.6 29.5 25.8 35.1 42.6 40.4 38.8 37.4
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 20.0 20.0 19.3 18.6 23.3 22.1 19.8 12.8 18.5 21.8 19.4 19.0 19.6
Milner ROR 4.7 4.7 0.0 0.0 9.5 9.4 6.2 0.0 0.0 0.0 0.0 0.0 2.9
Shoshone Falls ROR 12.0 11.9 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.4 8.1 8.9 9.1
Swan Falls ROR 14.0 13.9 14.1 13.5 14.5 12.4 10.6 9.2 12.6 14.4 14.0 13.6 13.1
Twin Falls ROR 8.4 7.9 3.8 0.0 12.2 12.9 10.1 0.0 0.0 4.6 4.4 5.3 5.8
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 11.6 11.8 11.4 10.9 14.5 13.3 11.5 6.4 10.5 12.9 11.0 10.8 11.4
Upper Salmon 3&4 ROR 11.2 11.3 10.9 10.5 13.6 12.6 11.1 6.7 10.2 12.2 10.6 10.5 11.0
HCC Total 451.1 423.2 502.6 568.4 615.6 447.1 474.2 316.1 298.4 360.0 347.4 398.2 433.5
ROR Total 182.0 182.3 176.7 186.4 275.1 278.8 261.5 185.0 185.8 191.0 167.7 166.1 203.2
Total 633.1 605.5 679.3 754.8 890.7 725.9 735.7 501.1 484.2 551.0 515.1 564.3 636.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 164 2015 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2033 2/2033 3/2033 4/2033 5/2033 6/2033 7/2033 8/2033 9/2033 10/2033 11/2033 12/2033 aMW
Brownlee HCC* 200.5 179.7 220.9 250.9 271.5 198.9 210.2 134.0 125.2 154.3 150.4 174.0 189.2
Oxbow HCC 83.9 78.5 92.4 104.5 112.4 81.9 88.5 60.8 56.5 69.2 65.7 75.2 80.8
Hells Canyon HCC 165.9 156.0 187.8 212.1 230.7 165.5 174.0 119.7 111.6 136.6 130.5 148.6 161.6
1000 Springs ROR**0.0 0.0 7.7 29.6 68.5 84.4 85.7 55.6 26.2 9.4 0.0 0.0 30.6
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 32.2 32.0 31.9 31.6 35.5 33.1 31.0 23.8 30.9 34.8 31.8 31.3 31.7
C .J. Strike ROR 40.0 40.0 41.1 38.7 40.6 34.4 29.2 25.6 34.8 42.4 40.1 38.5 37.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Clear Lake ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
Lower Malad ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Lower Salmon ROR 19.9 19.8 19.2 18.5 23.2 21.7 19.6 12.7 18.3 21.7 19.2 18.9 19.4
Milner ROR 4.7 4.7 0.0 0.0 8.7 8.6 6.2 0.0 0.0 0.0 0.0 0.0 2.7
Shoshone Falls ROR 12.0 11.9 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.4 8.1 8.9 9.1
Swan Falls ROR 14.0 13.8 14.1 13.4 14.4 12.0 10.5 9.1 12.5 14.3 13.9 13.6 13.0
Twin Falls ROR 8.4 7.9 3.8 0.0 11.4 12.3 10.1 0.0 0.0 4.6 4.4 5.3 5.7
Upper Malad ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Upper Salmon 1&2 ROR 11.5 11.6 11.3 10.8 14.4 13.0 11.4 6.3 10.3 12.8 10.9 10.7 11.3
Upper Salmon 3&4 ROR 11.1 11.2 10.9 10.5 13.5 12.3 11.0 6.6 10.0 12.1 10.5 10.4 10.8
HCC Total 450.3 414.2 501.1 567.5 614.6 446.3 472.7 314.5 293.3 360.1 346.6 397.8 431.6
ROR Total 181.3 181.4 176.3 185.8 272.4 275.2 260.6 184.1 184.5 190.2 166.7 165.3 202.0
Total 631.6 595.6 677.4 753.3 887.0 721.5 733.3 498.6 477.8 550.3 513.3 563.1 633.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90 Percentile Water, 70 Percentile Load
Resource Type 1/2034 2/2034 3/2034 4/2034 5/2034 6/2034 7/2034 8/2034 9/2034 10/2034 11/2034 12/2034 aMW
Brownlee HCC* 200.1 177.6 220.2 250.5 271.1 198.6 209.7 133.3 123.7 154.2 150.5 173.4 188.6
Oxbow HCC 83.7 77.5 92.1 104.3 112.2 81.8 88.3 60.4 55.8 69.0 65.7 74.9 80.5
Hells Canyon HCC 165.6 154.2 187.2 211.7 230.4 165.3 173.5 119.1 110.2 136.3 130.5 148.1 161.0
1000 Springs ROR**0.0 0.0 7.7 29.4 66.9 84.1 85.7 55.6 26.2 9.8 0.0 0.0 30.5
American Falls ROR 6.2 6.3 6.2 5.9 6.0 6.0 5.9 6.1 6.2 6.2 6.2 6.2 6.1
Bliss ROR 1.8 1.8 1.8 1.7 1.7 1.7 1.7 1.7 1.8 1.9 1.9 1.9 1.8
C .J. Strike ROR 6.5 7.0 7.0 7.2 7.5 7.2 7.1 7.2 7.4 7.1 6.5 6.6 7.0
Cascade ROR 11.5 12.0 12.7 12.8 13.5 12.3 12.2 12.6 13.3 13.0 11.9 11.8 12.5
Clear Lake ROR 8.4 7.8 3.8 0.0 11.1 12.1 10.1 0.0 0.0 4.6 4.4 5.3 5.6
Lower Malad ROR 12.0 11.8 7.3 3.9 12.0 12.0 12.0 6.5 6.5 8.4 8.1 8.9 9.1
Lower Salmon ROR 11.0 10.9 10.8 10.4 13.4 12.1 10.9 6.5 9.9 12.0 10.4 10.3 10.7
Milner ROR 11.4 11.4 11.2 10.8 14.2 12.8 11.3 6.2 10.2 12.6 10.7 10.6 11.1
Shoshone Falls ROR 19.7 19.4 19.1 18.5 23.0 21.4 19.5 12.5 18.1 21.5 19.0 18.7 19.2
Swan Falls ROR 32.1 31.9 31.8 31.5 35.1 33.0 30.9 23.6 30.7 34.6 31.6 31.2 31.5
Twin Falls ROR 39.8 39.9 40.9 38.4 39.5 34.1 29.0 25.4 34.5 42.2 39.9 38.3 36.8
Upper Malad ROR 13.9 13.8 14.1 13.3 13.9 11.9 10.5 9.0 12.4 14.3 13.7 13.4 12.9
Upper Salmon 1&2 ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.4 1.4 1.3 1.3 3.2
Upper Salmon 3&4 ROR 4.6 4.1 0.0 0.0 8.3 8.2 6.2 0.0 0.0 0.0 0.0 0.0 2.6
HCC Total 449.4 409.3 499.5 566.5 613.6 445.7 471.5 312.8 289.7 359.5 346.7 396.4 430.1
ROR Total 180.4 179.5 175.7 185.0 267.6 273.1 260.0 183.2 183.5 189.7 165.6 164.4 200.7
Total 629.8 588.8 675.2 751.5 881.2 718.8 731.5 496.0 473.2 549.2 512.3 560.8 630.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2015 Integrated Resource Plan—Appendix C Page 165
PORTFOLIO ANALYSIS, RESULTS,
AND SUPPORTING DOCUMENTATION
Portfolio Emissions
IPC Systems
CO2 Emission

NOx Emission

87,000,000
88,000,000
89,000,000
90,000,000
91,000,000
92,000,000
93,000,000
94,000,000
95,000,000
96,000,000
97,000,000
P_2a P_2b P_3 P_6 P_6b P_8 P_9 P_10 P_11 P_13 P_16 P_17 P_18
To
t
a
l

T
o
n
s

C
O
2

(
2
0
1
5
-20
3
4
)
0
10,000
20,000
30,000
40,000
50,000
60,000
P_2a P_2b P_3 P_6 P_6b P_8 P_9 P_10 P_11 P_13 P_16 P_17 P_18
To
t
a
l

T
o
n
s

N
O
X

(
2
0
1
5
-20
3
4
)
Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 166 2015 Integrated Resource Plan—Appendix C
HG Emission

SO2 Emission

0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0.4
P_2a P_2b P_3 P_6 P_6b P_8 P_9 P_10 P_11 P_13 P_16 P_17 P_18
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
90,000
100,000
P_2a P_2b P_3 P_6 P_6b P_8 P_9 P_10 P_11 P_13 P_16 P_17 P_18
Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2015 Integrated Resource Plan—Appendix C Page 167
Loss of Load Expectation Analysis
Loss of Load Expectation Summary Data (Hours per month)–Portfolio 2a
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2023 0.52 0.00 0.00 0.00 0.00 0.00 0.00 0.52 0.00 0.00 0.00 0.00 0.00
2024 1.04 0.00 0.00 0.00 0.00 0.00 0.01 1.03 0.00 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2027 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00
2028 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.00 0.00 0.00 0.00 0.00
2029 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.15 0.00 0.00 0.00 0.00 0.00
2030 0.27 0.00 0.00 0.00 0.00 0.00 0.00 0.27 0.00 0.00 0.00 0.00 0.00
2031 0.49 0.00 0.00 0.00 0.00 0.00 0.00 0.49 0.00 0.00 0.00 0.00 0.00
2032 0.87 0.00 0.00 0.00 0.00 0.00 0.00 0.87 0.00 0.00 0.00 0.00 0.00
2033 1.54 0.00 0.00 0.00 0.00 0.00 0.00 1.54 0.00 0.00 0.00 0.00 0.00
2034 1.86 0.00 0.00 0.00 0.00 0.00 0.01 1.85 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 168 2015 Integrated Resource Plan—Appendix C
Loss of Load Expectation Summary Data* (Hours per month)–Portfolio 3
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.04 0.00 0.00 0.00 0.00 0.00 0.01 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.95 0.00 0.00 0.00 0.00 0.00 0.01 0.93 0.01 0.00 0.00 0.00 0.00
2021 1.46 0.00 0.00 0.00 0.00 0.00 0.01 1.43 0.02 0.00 0.00 0.00 0.00
2022 1.35 0.00 0.00 0.00 0.00 0.00 0.01 1.32 0.01 0.00 0.00 0.00 0.00
2023 1.51 0.00 0.00 0.00 0.00 0.00 0.02 1.47 0.02 0.00 0.00 0.00 0.00
2024 2.55 0.00 0.00 0.00 0.00 0.00 0.04 2.48 0.02 0.01 0.00 0.00 0.00
2025 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00
2026 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.00 0.00 0.00 0.00 0.00
2027 0.12 0.00 0.00 0.00 0.00 0.00 0.00 0.12 0.00 0.00 0.00 0.00 0.00
2028 0.23 0.00 0.00 0.00 0.00 0.00 0.00 0.22 0.00 0.00 0.00 0.00 0.00
2029 0.36 0.00 0.00 0.00 0.00 0.00 0.00 0.36 0.00 0.00 0.00 0.00 0.00
2030 0.61 0.00 0.00 0.00 0.00 0.00 0.00 0.61 0.00 0.00 0.00 0.00 0.00
2031 0.96 0.00 0.00 0.00 0.00 0.00 0.00 0.95 0.00 0.00 0.00 0.00 0.00
2032 1.56 0.00 0.00 0.00 0.00 0.00 0.01 1.55 0.00 0.00 0.00 0.00 0.00
2033 2.16 0.00 0.00 0.00 0.00 0.00 0.01 2.14 0.01 0.00 0.00 0.00 0.00
2034 3.10 0.00 0.00 0.00 0.00 0.00 0.01 3.08 0.01 0.00 0.00 0.00 0.00
* With CBM@330 MW

Loss of Load Expectation Summary Data* (Hours per month)–Portfolio 6b
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2023 0.52 0.00 0.00 0.00 0.00 0.00 0.00 0.52 0.00 0.00 0.00 0.00 0.00
2024 1.04 0.00 0.00 0.00 0.00 0.00 0.01 1.03 0.00 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.22 0.00 0.00 0.00 0.00 0.00 0.00 0.22 0.00 0.00 0.00 0.00 0.00
2027 0.44 0.00 0.00 0.00 0.00 0.00 0.00 0.43 0.00 0.00 0.00 0.00 0.00
2028 0.85 0.00 0.00 0.00 0.00 0.00 0.00 0.84 0.00 0.00 0.00 0.00 0.00
2029 1.44 0.00 0.00 0.00 0.00 0.00 0.01 1.42 0.00 0.00 0.00 0.00 0.00
2030 1.95 0.00 0.00 0.00 0.00 0.00 0.02 1.93 0.00 0.00 0.00 0.00 0.00
2031 0.28 0.00 0.00 0.00 0.00 0.00 0.00 0.28 0.00 0.00 0.00 0.00 0.00
2032 0.54 0.00 0.00 0.00 0.00 0.00 0.00 0.54 0.00 0.00 0.00 0.00 0.00
2033 0.87 0.00 0.00 0.00 0.00 0.00 0.00 0.86 0.00 0.00 0.00 0.00 0.00
2034 1.49 0.00 0.00 0.00 0.00 0.00 0.01 1.48 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW
Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2015 Integrated Resource Plan—Appendix C Page 169

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 8
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.04 0.00 0.00 0.00 0.00 0.00 0.01 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.29 0.00 0.00 0.00 0.00 0.00 0.00 0.28 0.00 0.00 0.00 0.00 0.00
2021 0.83 0.00 0.00 0.00 0.00 0.00 0.01 0.81 0.01 0.00 0.00 0.00 0.00
2022 0.81 0.00 0.00 0.00 0.00 0.00 0.01 0.80 0.01 0.00 0.00 0.00 0.00
2023 1.21 0.00 0.00 0.00 0.00 0.00 0.01 1.19 0.01 0.00 0.00 0.00 0.00
2024 1.49 0.00 0.00 0.00 0.00 0.00 0.02 1.47 0.01 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.00 0.00 0.00 0.00 0.00
2027 0.21 0.00 0.00 0.00 0.00 0.00 0.00 0.21 0.00 0.00 0.00 0.00 0.00
2028 0.38 0.00 0.00 0.00 0.00 0.00 0.00 0.38 0.00 0.00 0.00 0.00 0.00
2029 0.71 0.00 0.00 0.00 0.00 0.00 0.00 0.71 0.00 0.00 0.00 0.00 0.00
2030 1.20 0.00 0.00 0.00 0.00 0.00 0.01 1.19 0.00 0.00 0.00 0.00 0.00
2031 1.36 0.00 0.00 0.00 0.00 0.00 0.01 1.35 0.00 0.00 0.00 0.00 0.00
2032 1.23 0.00 0.00 0.00 0.00 0.00 0.00 1.23 0.00 0.00 0.00 0.00 0.00
2033 1.28 0.00 0.00 0.00 0.00 0.00 0.00 1.27 0.00 0.00 0.00 0.00 0.00
2034 1.96 0.00 0.00 0.00 0.00 0.00 0.00 1.96 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 9
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2021 0.94 0.00 0.00 0.00 0.00 0.00 0.01 0.92 0.01 0.00 0.00 0.00 0.00
2022 0.91 0.00 0.00 0.00 0.00 0.00 0.01 0.90 0.01 0.00 0.00 0.00 0.00
2023 1.45 0.00 0.00 0.00 0.00 0.00 0.01 1.42 0.01 0.00 0.00 0.00 0.00
2024 1.47 0.00 0.00 0.00 0.00 0.00 0.02 1.44 0.01 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.10 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00
2027 0.20 0.00 0.00 0.00 0.00 0.00 0.00 0.20 0.00 0.00 0.00 0.00 0.00
2028 0.42 0.00 0.00 0.00 0.00 0.00 0.00 0.42 0.00 0.00 0.00 0.00 0.00
2029 0.69 0.00 0.00 0.00 0.00 0.00 0.01 0.68 0.00 0.00 0.00 0.00 0.00
2030 1.33 0.00 0.00 0.00 0.00 0.00 0.01 1.31 0.00 0.00 0.00 0.00 0.00
2031 1.85 0.00 0.00 0.00 0.00 0.00 0.01 1.84 0.00 0.00 0.00 0.00 0.00
2032 0.72 0.00 0.00 0.00 0.00 0.00 0.00 0.71 0.00 0.00 0.00 0.00 0.00
2033 1.35 0.00 0.00 0.00 0.00 0.00 0.00 1.35 0.00 0.00 0.00 0.00 0.00
2034 2.08 0.00 0.00 0.00 0.00 0.00 0.01 2.07 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW
Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 170 2015 Integrated Resource Plan—Appendix C

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 10
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2023 0.52 0.00 0.00 0.00 0.00 0.00 0.00 0.52 0.00 0.00 0.00 0.00 0.00
2024 0.89 0.00 0.00 0.00 0.00 0.00 0.01 0.88 0.00 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2027 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00
2028 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.00 0.00 0.00 0.00 0.00
2029 0.12 0.00 0.00 0.00 0.00 0.00 0.00 0.12 0.00 0.00 0.00 0.00 0.00
2030 0.22 0.00 0.00 0.00 0.00 0.00 0.00 0.22 0.00 0.00 0.00 0.00 0.00
2031 0.42 0.00 0.00 0.00 0.00 0.00 0.00 0.42 0.00 0.00 0.00 0.00 0.00
2032 0.75 0.00 0.00 0.00 0.00 0.00 0.00 0.75 0.00 0.00 0.00 0.00 0.00
2033 0.47 0.00 0.00 0.00 0.00 0.00 0.00 0.47 0.00 0.00 0.00 0.00 0.00
2034 0.73 0.00 0.00 0.00 0.00 0.00 0.00 0.73 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 11
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.04 0.00 0.00 0.00 0.00 0.00 0.01 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.08 0.00 0.00 0.00 0.00 0.00 0.00 0.08 0.00 0.00 0.00 0.00 0.00
2021 0.29 0.00 0.00 0.00 0.00 0.00 0.00 0.29 0.00 0.00 0.00 0.00 0.00
2022 0.28 0.00 0.00 0.00 0.00 0.00 0.00 0.28 0.00 0.00 0.00 0.00 0.00
2023 0.47 0.00 0.00 0.00 0.00 0.00 0.00 0.47 0.00 0.00 0.00 0.00 0.00
2024 1.55 0.00 0.00 0.00 0.00 0.00 0.02 1.52 0.01 0.00 0.00 0.00 0.00
2025 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2026 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00
2027 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.00 0.00 0.00 0.00 0.00
2028 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.00 0.00 0.00 0.00 0.00
2029 0.21 0.00 0.00 0.00 0.00 0.00 0.00 0.21 0.00 0.00 0.00 0.00 0.00
2030 0.36 0.00 0.00 0.00 0.00 0.00 0.00 0.36 0.00 0.00 0.00 0.00 0.00
2031 0.62 0.00 0.00 0.00 0.00 0.00 0.00 0.61 0.00 0.00 0.00 0.00 0.00
2032 0.37 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.00 0.00 0.00 0.00 0.00
2033 1.15 0.00 0.00 0.00 0.00 0.00 0.00 1.14 0.00 0.00 0.00 0.00 0.00
2034 1.30 0.00 0.00 0.00 0.00 0.00 0.00 1.29 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW
Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2015 Integrated Resource Plan—Appendix C Page 171

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 13
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2023 0.52 0.00 0.00 0.00 0.00 0.00 0.00 0.52 0.00 0.00 0.00 0.00 0.00
2024 0.89 0.00 0.00 0.00 0.00 0.00 0.01 0.88 0.00 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.19 0.00 0.00 0.00 0.00 0.00 0.00 0.18 0.00 0.00 0.00 0.00 0.00
2027 0.37 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.00 0.00 0.00 0.00 0.00
2028 0.70 0.00 0.00 0.00 0.00 0.00 0.00 0.70 0.00 0.00 0.00 0.00 0.00
2029 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.00 0.00 0.00 0.00 0.00
2030 0.19 0.00 0.00 0.00 0.00 0.00 0.00 0.19 0.00 0.00 0.00 0.00 0.00
2031 0.35 0.00 0.00 0.00 0.00 0.00 0.00 0.35 0.00 0.00 0.00 0.00 0.00
2032 0.62 0.00 0.00 0.00 0.00 0.00 0.00 0.62 0.00 0.00 0.00 0.00 0.00
2033 0.38 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.00 0.00 0.00 0.00 0.00
2034 0.60 0.00 0.00 0.00 0.00 0.00 0.00 0.60 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2021 0.94 0.00 0.00 0.00 0.00 0.00 0.01 0.92 0.01 0.00 0.00 0.00 0.00
2022 0.91 0.00 0.00 0.00 0.00 0.00 0.01 0.90 0.01 0.00 0.00 0.00 0.00
2023 1.45 0.00 0.00 0.00 0.00 0.00 0.01 1.42 0.01 0.00 0.00 0.00 0.00
2024 1.47 0.00 0.00 0.00 0.00 0.00 0.02 1.44 0.01 0.00 0.00 0.00 0.00
2025 1.77 0.00 0.00 0.00 0.00 0.00 0.01 1.75 0.01 0.00 0.00 0.00 0.00
2026 0.90 0.00 0.00 0.00 0.00 0.00 0.01 0.89 0.00 0.00 0.00 0.00 0.00
2027 1.55 0.00 0.00 0.00 0.00 0.00 0.01 1.52 0.01 0.00 0.00 0.00 0.00
2028 2.79 0.00 0.00 0.00 0.00 0.00 0.02 2.76 0.01 0.00 0.00 0.00 0.00
2029 1.14 0.00 0.00 0.00 0.00 0.00 0.02 1.12 0.00 0.00 0.00 0.00 0.00
2030 1.99 0.00 0.00 0.00 0.00 0.00 0.03 1.95 0.01 0.00 0.00 0.00 0.00
2031 2.69 0.00 0.00 0.00 0.00 0.00 0.02 2.66 0.01 0.00 0.00 0.00 0.00
2032 1.12 0.00 0.00 0.00 0.00 0.00 0.00 1.12 0.00 0.00 0.00 0.00 0.00
2033 2.02 0.00 0.00 0.00 0.00 0.00 0.01 2.01 0.00 0.00 0.00 0.00 0.00
2034 2.95 0.00 0.00 0.00 0.00 0.00 0.02 2.92 0.01 0.00 0.00 0.00 0.00
* With CBM@330 MW
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Loss of Load Expectation Summary Data (Hours per month)–Portfolio 17
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2023 0.52 0.00 0.00 0.00 0.00 0.00 0.00 0.52 0.00 0.00 0.00 0.00 0.00
2024 1.61 0.00 0.00 0.00 0.00 0.00 0.02 1.58 0.01 0.00 0.00 0.00 0.00
2025 1.81 0.00 0.00 0.00 0.00 0.00 0.01 1.79 0.01 0.00 0.00 0.00 0.00
2026 1.86 0.00 0.00 0.00 0.00 0.00 0.01 1.84 0.01 0.00 0.00 0.00 0.00
2027 2.09 0.00 0.00 0.00 0.00 0.00 0.02 2.06 0.01 0.00 0.00 0.00 0.00
2028 2.16 0.00 0.00 0.00 0.00 0.00 0.01 2.14 0.01 0.00 0.00 0.00 0.00
2029 2.26 0.00 0.00 0.00 0.00 0.00 0.02 2.23 0.01 0.00 0.00 0.00 0.00
2030 0.34 0.00 0.00 0.00 0.00 0.00 0.00 0.34 0.00 0.00 0.00 0.00 0.00
2031 0.59 0.00 0.00 0.00 0.00 0.00 0.00 0.59 0.00 0.00 0.00 0.00 0.00
2032 0.97 0.00 0.00 0.00 0.00 0.00 0.00 0.97 0.00 0.00 0.00 0.00 0.00
2033 1.36 0.00 0.00 0.00 0.00 0.00 0.01 1.35 0.00 0.00 0.00 0.00 0.00
2034 2.07 0.00 0.00 0.00 0.00 0.00 0.01 2.06 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Loss of Load Expectation Summary Data (Hours per month)–Portfolio 18
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2015 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.09 0.00 0.00 0.00 0.00 0.00
2016 0.10 0.00 0.00 0.00 0.00 0.00 0.01 0.09 0.00 0.00 0.00 0.00 0.00
2017 0.02 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00 0.00
2018 0.05 0.00 0.00 0.00 0.00 0.00 0.02 0.03 0.00 0.00 0.00 0.00 0.00
2019 0.09 0.00 0.00 0.00 0.00 0.00 0.04 0.05 0.00 0.00 0.00 0.00 0.00
2020 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00
2021 0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.00 0.00 0.00 0.00
2022 0.91 0.00 0.00 0.00 0.00 0.00 0.01 0.90 0.01 0.00 0.00 0.00 0.00
2023 1.42 0.00 0.00 0.00 0.00 0.00 0.01 1.39 0.01 0.00 0.00 0.00 0.00
2024 1.59 0.00 0.00 0.00 0.00 0.00 0.02 1.56 0.01 0.00 0.00 0.00 0.00
2025 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00
2026 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.00 0.00 0.00 0.00 0.00
2027 0.20 0.00 0.00 0.00 0.00 0.00 0.00 0.20 0.00 0.00 0.00 0.00 0.00
2028 0.44 0.00 0.00 0.00 0.00 0.00 0.00 0.43 0.00 0.00 0.00 0.00 0.00
2029 0.73 0.00 0.00 0.00 0.00 0.00 0.01 0.72 0.00 0.00 0.00 0.00 0.00
2030 1.34 0.00 0.00 0.00 0.00 0.00 0.01 1.33 0.00 0.00 0.00 0.00 0.00
2031 1.48 0.00 0.00 0.00 0.00 0.00 0.01 1.47 0.00 0.00 0.00 0.00 0.00
2032 1.78 0.00 0.00 0.00 0.00 0.00 0.01 1.77 0.00 0.00 0.00 0.00 0.00
2033 1.85 0.00 0.00 0.00 0.00 0.00 0.01 1.84 0.00 0.00 0.00 0.00 0.00
2034 2.37 0.00 0.00 0.00 0.00 0.00 0.01 2.35 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

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Compliance with State of Oregon IRP Guidelines
Oregon Order 07-047 Action Items 2015 IRP
Guideline 1: Substantive Requirements
a. All resources must be evaluated on a consistent and comparable basis.
• All known resources for meeting the utility’s load should be considered, including supply-side options
which focus on the generation, purchase and transmission of power – or gas purchases, transportation, and storage – and demand side options which focus on conservation and demand response.
• Utilities should compare different resource fuel types, technologies, lead times, in-service dates, durations and locations in portfolio risk modeling.
• Consistent assumptions and methods should be used for evaluation of all resources.
• The after-tax marginal weighted-average cost of capital (WACC) should be used to discount all future
resource costs.
b. Risk and uncertainty must be considered.
• At a minimum, utilities should address the following sources of risk and uncertainty:
1. Electric utilities: load requirements, hydroelectric generation, plant forced outages, fuel prices, electricity prices, and costs to comply with any regulation of greenhouse gas emissions.
2. Natural gas utilities: demand (peak, swing and baseload), commodity supply and price, transportation availability and price, and costs to comply with any regulation of greenhouse gas emissions.
• Utilities should identify in their plans any additional sources of risk and uncertainty.
c. The primary goal must be the selection of a portfolio of resources with the best combination of expected costs and associated risks and uncertainties for the utility and its customers.
• The planning horizon for analyzing resource choices should be at least 20 years and account for end effects. Utilities should consider all costs with a
reasonable likelihood of being included in rates over the long term, which extends beyond the planning horizon and the life of the resource.
• Utilities should use present value of revenue requirement (PVRR) as the key cost metric. The plan should include analysis of current and estimated future costs for all longlived resources such as power plants, gas storage facilities, and pipelines, as well as
all short-lived resources such as gas supply and short-term power purchases.
• To address risk, the plan should include, at a minimum:
1. Two measures of PVRR risk: one that measures the variability of costs and one that measures the severity of bad outcomes.
2. Discussion of the proposed use and impact on costs and risks of physical and financial hedging.
• The utility should explain in its plan how its resource choices appropriately balance cost and risk.
d. The plan must be consistent with the long-run public interest as expressed in Oregon and federal energy policies.
a-1) Supply-side and purchased resources for meeting the utility’s load are discussed in Chapter 3 (Idaho Power Today), section Existing Supply-Side Resources, pages 27–38. Demand-side options for meeting the utility’s load are discussed in Chapter 4 (Demand-Side Resources). Chapter 6 (Transmission Planning) discusses transmission resources for meeting the utility’s load.
a-2) New resource options are described in Chapters 4 through 7. Chapter 4 (Demand-Side Resources) describes demand-side resource options for IRP resource portfolios. Chapter 5 (Supply-Side Generation and Storage Resources) describes generating resources and energy storage resources to be considered for IRP resource portfolios. Chapter 6 (Transmission Planning) describes transmission resources considered for IRP resource portfolios. Chapter 7
(Planning Period Forecasts) provides resource cost information.
a-3) The consistent modeling method for evaluating new resource options is described in Chapter 7 (Planning Period Forecasts), sections Resource Cost Analysis, Resource Cost Analysis II—Resource Stack, and Supply-Side Resource Costs. The consistent
modeling method for evaluating all resource portfolios is explained in Chapter 9 (Modeling Analysis and Results), pages 113–114.
a-4) The WACC rate used to discount all future resource costs is stated in Chapter 9 (Modeling Analysis and Results), in Table 9.1 Financial Assumptions, on page 114.
b-1) Electric utility risk and uncertainty factors (load, NG and water conditions) for resource portfolios are considered in Chapter 9 (Modeling Analysis and Results), section Stochastic Risk Analysis, pages 121–124. (For electricity prices, AURORA forecasts electric market prices; therefore AURORA variables are changed to create different electric market price scenarios). Sensitivity analysis for CAA Section 111(d) performed to address costs to comply with greenhouse gas regulations is discussed in Chapter 9 (Modeling Analysis and Results), section CAA Section 111(d) Sensitivity Analysis, beginning on page 114.
Note: Plant forced outages for resource options and resource portfolios are not discussed in the IRP document or 2015 IRP Technical Appendix. Plant forced outages are modeled in AURORA on a unit basis.
b-1-other) Additional sources of risk and uncertainty are identified in Chapter 2 (Political, Regulatory, and Operational Issues) in the
following sections: FERC Relicensing, page 14; Idaho Water Issues, page 15; Northwest Power Pool Energy Imbalance Market, page 19; and Federal Energy Legislation CAA Section 111(d), page 21.
Further discussion of risks is included in Chapter 9 (Modeling Analysis and Results), in section Qualitative Risk Analysis, beginning
on page 125. Uncertainty factoring into the selection of the preferred portfolio is expressed in Chapter 1 (Summary) on pages 8-10.
c-1) The IRP methodology and the planning horizon of 20 years are discussed in Chapter 1 (Summary), section IRP Methodology, page 3.
c-2) Idaho Power uses the company’s internal P-Worth model to calculate the PVRR for the capital component of the various portfolios. AURORA is used to model the variable (operating) component of the various portfolios. All costs are then discounted using the company’s WACC. The summary of the NPV accounting for
total portfolio costs is provided in Chapter 9 (Modeling Analysis and Results), pages 113-114.
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Oregon Order 07-047 Action Items 2015 IRP
c-1.) Measures of the variability of costs and the severity of bad outcomes are considered in Chapter 9 (Modeling Analysis and Results), section Stochastic Risk Analysis, pages 121–124. A discussion of extreme outcomes, including extreme bad outcomes, is provided in the Stochastic Risk Analysis section in the third
paragraph of page 123.
c-2.) The risks of physical and financial hedging are referenced to Idaho Power’s Energy Risk Management Policy discussed in Chapter 1 (Summary), in the last paragraph of section Introduction, on page 2. Idaho Power explains how its preferred portfolio
appropriately balances cost and risk in Chapter 9 (Modeling Analysis and Results), section Preferred Portfolio, page 130. The accounting for qualitative risks and uncertainty in the preferred portfolio selection is discussed in Chapter 1 (Summary), section Portfolio Analysis Summary, beginning on page 8. Further discussion of the preferred
portfolio’s appropriate balancing of cost and risk is included in Chapter 10 (Preferred Portfolio and Action Plan), section Preferred Portfolio (2015-2034), page 141.
d-1) The plan is consistent with long-run public interests and is discussed in Chapter 2 (Political, Regulatory, and Operational
Issues). Additional discussion relevant to this requirement is in Chapter 1 (Summary), section Public Advisory Process, pages 2–3.
Guideline 2: Procedural Requirements.
a. The public, which includes other utilities, should be allowed significant involvement in the preparation of the IRP.
Involvement includes opportunities to contribute information and ideas, as well as to receive information. Parties must have an opportunity to make relevant inquiries of the utility formulating the plan. Disputes about whether information requests are relevant or unreasonably burdensome, or whether a utility is
being properly responsive, may be submitted to the Commission for resolution.
b. While confidential information must be protected, the utility should make public, in its plan, any non-confidential information that is relevant to its resource evaluation and action plan.
Confidential information may be protected through use of a protective order, through aggregation or shielding of data, or through any other mechanism approved by the Commission.
c. The utility must provide a draft IRP for public review and comment prior to filing a final plan with the Commission.
As set forth in Guideline 2, part a., Idaho Power solicits public involvement in the planning process. The company convenes a public forum as part of the resource planning process. For the 2004, 2006, 2009, 2011, 2013, and 2015 plans, Idaho Power assembled an IRP Advisory Council composed of customer representatives, representatives from both the Idaho and Oregon public utility commission staffs, and representatives from special interest groups. A roster of the IRP Advisory Council members is provided in the
technical appendices of the IRPs. The IRP Advisory Council meetings are open to the public. IRP Advisory Council meetings are attended by members of the public and Idaho Power has involved the public participants in the IRP Advisory Council’s discussions. These meetings allow parties to make relevant inquiries of Idaho Power
formulating the plan.
As set forth in Guideline 2, part b., Idaho Power makes public extensive information relevant to its resource evaluation and action plan in its plan. This information is found throughout the 2015 IRP, the 2015 Load and Sales Forecast and in the 2015
Technical Appendix.
As set forth in Guideline 2, part c., Idaho Power posted online a draft 2015 IRP for public review on Thursday, June 4, 2015. The company requested for comments to be provided no later than Friday, June 12, 2015.
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Oregon Order 07-047 Action Items 2015 IRP
Guideline 3: Plan Filing, Review, and Updates.
a. A utility must file an IRP within two years of its previous IRP acknowledgment order. If the utility does not intend to take any significant resource action for at least two years after its next IRP is due, the utility may request an extension of its filing date
from the Commission.
b. The utility must present the results of its filed plan to the Commission at a public meeting prior to the deadline for written public comment.
c. Commission staff and parties should complete their
comments and recommendations within six months of IRP filing.
d. The Commission will consider comments and recommendations on a utility’s plan at a public meeting before issuing an order on acknowledgment. The Commission may provide the utility an opportunity to revise the plan before issuing
an acknowledgment order.
e. The Commission may provide direction to a utility regarding any additional analyses or actions that the utility should undertake in its next IRP.
f. Each utility must submit an annual update on its most recently acknowledged plan. The update is due on or before the acknowledgment order anniversary date. Once a utility anticipates a significant deviation from its acknowledged IRP, it must file an update with the Commission, unless the utility is within six months of filing its next IRP. The utility must
summarize the update at a Commission public meeting. The utility may request acknowledgment of changes in proposed actions identified in an update.
g. Unless the utility requests acknowledgement of changes in proposed actions, the annual update is an informational
filing that:
• Describes what actions the utility has taken to implement the plan;
• Provides an assessment of what has changed since the acknowledgment order that affects the action plan, including changes in such factors as load, expiration of resource contracts, supply-side and demand-side resource acquisitions, resource costs, and transmission availability; and
• Justifies any deviations from the acknowledged action plan.
a. The OPUC acknowledged Idaho Power’s 2013 IRP on July 8, 2014 in Order 14-253. Idaho Power plans to file the 2015 IRP by June 30, 2015.
b. Idaho Power will schedule a public meeting at the OPUC after the 2015 IRP has been filed.
c. No action needed.
d. No action needed unless the OPUC provides Idaho Power an opportunity to revise the plan.
e. In Order No. 12-013, the OPUC provided direction on IRP flexible resource guidelines. In Order No. 14-253, the OPUC provided its resolution of fourteen components of the 2013 IRP. Idaho Power has addressed these action items in the 2015 IRP.
f. In Order No. 14-253, the OPUC waived for Idaho Power the requirement to file an annual update to the 2013 IRP, the most recently acknowledged IRP.
g. No action needed.
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Guideline 4: Plan Components.
At a minimum, the plan must include the following elements:
a. An explanation of how the utility met each of the substantive and procedural requirements;
b. Analysis of high and low load growth scenarios in
addition to stochastic load risk analysis with an explanation of major assumptions;
c. For electric utilities, a determination of the levels of peaking capacity and energy capability expected for each year of the plan, given existing resources; identification of
capacity and energy needed to bridge the gap between expected loads and resources; modeling of all existing transmission rights, as well as future transmission additions associated with the resource portfolios tested;
d. For natural gas utilities, a determination of the peaking,
swing and base-load gas supply and associated transportation and storage expected for each year of the plan, given existing resources; and identification of gas supplies (peak, swing and base-load), transportation and storage needed to bridge the gap between expected loads
and resources;
e. Identification and estimated costs of all supply-side and demand-side resource options, taking into account anticipated advances in technology;
f. Analysis of measures the utility intends to take to provide reliable service, including cost-risk tradeoffs;
g. Identification of key assumptions about the future (e.g., fuel prices and environmental compliance costs) and alternative scenarios considered;
h. Construction of a representative set of resource
portfolios to test various operating characteristics, resource types, fuels and sources, technologies, lead times, in-service dates, durations and general locations – system-wide or delivered to a specific portion of the system;
i. Evaluation of the performance of the candidate portfolios
over the range of identified risks and uncertainties;
j. Results of testing and rank ordering of the portfolios by cost and risk metric, and interpretation of those results;
k. Analysis of the uncertainties associated with each portfolio evaluated;
l. Selection of a portfolio that represents the best combination of cost and risk for the utility and its customers;
m. Identification and explanation of any inconsistencies of the selected portfolio with any state and federal energy policies that may affect a utility’s plan and any barriers to implementation; and
n. An action plan with resource activities the utility intends to undertake over the next two to four years to acquire the identified resources, regardless of whether the activity was acknowledged in a previous IRP, with the key attributes of each resource specified as in portfolio testing.
a. Idaho Power anticipates delivering this table in an informal letter to the OPUC staff.
b. Idaho Power revises the sales and load forecast each year and Idaho Power included the most recent sales and load forecast assumptions in Chapter 7 (Planning Period Forecasts), section Load Forecast, beginning on page 73.. High-growth scenarios at the 90th and 95th percentile levels for peak hour, and at the 70th and 90th percentile levels for energy are provided in Chapter 7, Figures 7.1 and 7.2 and Tables 7.1 and 7.2. High- and low-growth scenarios analyzed for the stochastic load risk
analysis are discussed in Chapter 9 (Modeling Analysis and Results), section Stochastic Risk Analysis, pages 121-124.
c. Peaking capacity and energy capability for each year of the plan for existing resources are discussed in Chapter 7 (Planning Period Forecasts), section Generation Forecast for Existing
Resources, beginning on page 80. Idaho Power uses AURORA in the modeling of all existing transmission. Future transmission additions associated with the resource portfolios tested are discussed in Chapter 6 (Transmission Planning), section Transmission Assumptions in the IRP Portfolios,
beginning on page 71.
d. Not applicable.
e. Supply-side resources considered are identified and described in Chapter 5 (Supply-Side Generation and Storage Resources). Resource costs are discussed and provided in Chapter 7 (Planning Period Forecasts), sections Resource Cost Analysis, Resource Cost Analysis II—Resource Stack, and Supply-Side Resource Costs. Demand-side resources and their levelized costs and technologies are covered in Chapter 4 (Demand-Side Resources).
f. Resource reliability is covered in Chapter 9 (Modeling Analysis and Results), section Loss of Load Expectation (LOLE), beginning on page 139.
g. Natural gas price forecasts are discussed in Chapter 7 (Planning Period Forecasts), section Natural Gas Price Forecast, page 84-85. Chapter 7 also includes key assumptions about future load in section Load Forecast and generation in section Generation Forecast for Existing Resources. Costs for environmental compliance with proposed CO2 regulations are addressed in Chapter 9 (Modeling Analysis and Results), section CAA Section
111(d) Sensitivity Analysis, beginning on page 114. Compliance alternatives to SCR installation at Jim Bridger Units 1 and 2 are addressed by portfolios considering early retirement of Jim Bridger Units 1 and 2. Environmental compliance costs for SCR installation at Jim Bridger units 3 and 4 are addressed in the
Appendix C—Technical Appendix in the section Jim Bridger Units 3 and 4 Selective Catalytic Reduction Analysis.
h. Resource portfolios considered for the 2015 IRP are described in Chapter 8 (Portfolio Selection). Resource portfolios were developed using resources from the resource stack provided in
Chapter 7 (Planning Period Forecasts), sections Resource Cost Analysis, Resource Cost Analysis II—Resource Stack, and Supply-Side Resource Costs. Resource portfolios were developed with consult from the IRP Advisory Council and public participants.
i. The resource portfolios are evaluated against various risks in Chapter 9, Modeling Analysis and Results, section Stochastic Risk Analysis, pages 121–124.
j. Portfolio cost and risk results, with interpretations, are provided in Chapter 9 (Modeling Analysis and Results).
k. The uncertainties associated with each portfolio are evaluated in Chapter 9 (Modeling Analysis and Results), sections Stochastic Risk Analysis and Qualitative Risk Analysis.
l. The selection reasoning for the preferred resource portfolio is identified in Chapter 9 (Modeling Analysis and Results), section
Preferred Portfolio, page 130.
m. No inconsistencies were identified.
n. An action plan is provided in Chapter 1 (Summary), section Action Plan, page 10.
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Guideline 5: Transmission.
Portfolio analysis should include costs to the utility for the fuel transportation and electric transmission required for each resource being considered. In addition, utilities should consider fuel transportation and electric transmission facilities as
resource options, taking into account their value for making additional purchases and sales, accessing less costly resources in remote locations, acquiring alternative fuel supplies, and improving reliability.
The transmission required for each resource being considered is described in the 2015 IRP Technical Appendix, section Transmission Cost Assumptions. Transmission assumptions for supply-side resources considered are included in Chapter 6 (Transmission Planning), section Transmission Assumptions in the IRP Portfolios,
pages 71–72. AURORA accounts for the cost of wheeling when selling and purchasing power from the market. For natural gas-fired resources, the Idaho Citygate price reflects the cost of transport to a power plant. The Idaho Citygate price is described in Chapter 7 (Planning Period Forecasts), section Natural Gas Price Forecast,
pages 84-85. Forecasts for Idaho Citygate price are provided in the 2015 IRP Technical Appendix, section Fuel Price Forecasts.
Guideline 6: Conservation.
a. Each utility should ensure that a conservation potential study is conducted periodically for its entire service territory.
b. To the extent that a utility controls the level of funding for conservation programs in its service territory, the utility should include in its action plan all best cost/risk portfolio conservation resources for meeting projected resource needs, specifying annual savings targets.
c. To the extent that an outside party administers conservation programs in a utility’s service territory at a level of funding that is beyond the utility’s control, the utility should:
• Determine the amount of conservation resources in the best cost/risk portfolio without regard to any limits on funding of conservation programs; and
• Identify the preferred portfolio and action plan consistent with the outside party’s projection of conservation acquisition.
a. The potential study conducted by Applied Energy Group (AEG) for the 2015 IRP is described in Chapter 4 (Demand-Side Resources), section Committed Energy Efficiency Forecast,
beginning on page 43.
b. The 2015 IRP action plan expresses Idaho Power’s intent to continue pursuit of cost-effective energy efficiency. A forecast for energy efficiency effects in five-year blocks is provided in Chapter 4 (Demand-Side Resources), section Committed
Energy Efficiency Forecast, Table 4.2. Detailed year-by-year forecast values are included in the 2015 IRP Technical Appendix, section Monthly average energy load and resource balance.
c. Treatment of third party market transformation savings provided by the Northwest Energy Efficiency Alliance (NEEA) in the 2015 IRP is discussed in Chapter 4 (Demand-Side Resource), pages 40-41. Idaho Power has changed how market transformation savings provided by NEEA are treated in the IRP. NEEA savings are now included as savings to meet targets because of the
overlap of NEEA initiatives and IPC’s most recent potential study.
Guideline 7: Demand Response.
Plans should evaluate demand response resources, including voluntary rate programs, on par with other options for
meeting energy, capacity, and transmission needs (for electric utilities) or gas supply and transportation needs (for natural gas utilities).
Demand response resources are detailed in Chapter 4 (Demand-Side Resources), section Demand Response Performance, page 42. Additional demand response above baseline levels is considered in
select portfolios, including the preferred portfolio. The additional demand response is discussed in Chapter 4 (Demand-Side Resources), section Additional Demand Response, page 47.
Guideline 8: Environmental Costs.
Utilities should include, in their base-case analyses, the
regulatory compliance costs they expect for carbon dioxide (CO2), nitrogen oxides, sulfur oxides, and mercury emissions. Utilities should analyze the range of potential CO2 regulatory costs in Order No. 93-695, from zero to $40 (1990$). In addition, utilities should perform sensitivity analysis on a range of reasonably possible cost adders for nitrogen oxides, sulfur oxides, and mercury, if applicable.
It is noted in Chapter 9 (Modeling Analysis and Results), section Portfolio Emissions, page 125, that with the exception of portfolios retiring Jim Bridger Units 1 and 2 without installation of NOx-controlling retrofits, all portfolios are designed to comply with environmental regulations. CAA Section 111(d) is modeled to reflect future carbon dioxide regulations. Portfolio costs provided for the considered CAA Section 111(d) sensitivities as provided in Chapter 9
(Modeling Analysis and Results), section CAA Section 111(d) sensitivity analysis – results, Table 9.4, page 119.
Guideline 9: Direct Access Loads.
An electric utility’s load-resource balance should exclude customer loads that are effectively committed to service by an
alternative electricity supplier.
At present, Idaho Power does not have any customers served by alternative electricity suppliers and Idaho Power has no direct access loads. Guideline 9 is not expected to apply to Idaho Power during the 2015 IRP 20-year planning period.
Guideline 10: Multi-state Utilities.
Multi-state utilities should plan their generation and transmission systems, or gas supply and delivery, on an integrated-system basis that achieves a best cost/risk portfolio for all their retail customers.
Idaho Power intends to file the 2015 IRP in both the Idaho and Oregon jurisdictions.
Guideline 11: Reliability.
Electric utilities should analyze reliability within the risk modeling of the actual portfolios being considered. Loss of load probability, expected planning reserve margin, and expected and worst-case unserved energy should be determined by year for top-performing portfolios. Natural gas utilities should analyze, on an integrated basis, gas supply, transportation, and storage, along with demandside resources, to reliably meet peak, swing, and base-load system requirements. Electric and natural gas
utility plans should demonstrate that the utility’s chosen portfolio achieves its stated reliability, cost and risk objectives.
Idaho Power discussed the capacity planning margin in Chapter 9 (Modeling Analysis and Results), section Capacity Planning Margin, beginning on page 131, and the loss of load probability in Chapter 9 (Modeling Analysis and Results), section Loss of Load Expectation, beginning on page 139.
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Guideline 12: Distributed Generation.
Electric utilities should evaluate distributed generation technologies on par with other supply-side resources and should consider, and quantify where possible, the additional benefits of distributed generation.
Idaho Power evaluated distributed solar PV as a resource option in portfolio 18. Portfolio 18 is described in Chapter 8 (Portfolio Selection), page 110. Distributed storage (ice-based thermal and V redox flow battery) resources were evaluated in multiple portfolios. Portfolios are described in Chapter 8 (Portfolio Selection), beginning
on page 97. Distributed resources, generating and storage, were credited to account for avoided transmission line losses.

Guideline 13: Resource Acquisition.
a. An electric utility should, in its IRP:
• Identify its proposed acquisition strategy for each resource in its action plan.
• Assess the advantages and disadvantages of owning a resource instead of purchasing power from another party.
• Identify any Benchmark Resources it plans to consider in competitive bidding.
b. Natural gas utilities should either describe in the IRP their bidding practices for gas supply and transportation, or provide a description of those practices following IRP acknowledgment.
Idaho Power continues to evaluate resource ownership along with other supply options. Idaho Power conducts its resource acquisition
and competitive bidding processes consistent with the guidelines established by Oregon in Order No. 14-149 issued on April 30, 2014.
Idaho Power discusses asset ownership in Chapter 10 (Action Plan), section Action Plan (2015–2018), page 143.
Idaho Power’s action plan includes ongoing permitting, planning
studies, and regulatory filings associated with the Boardman to Hemingway transmission line. Construction of the Boardman to Hemingway transmission line will be managed to be consistent with resource acquisition and competitive bidding processes provided in guidelines established by Oregon in Order No. 14-149.

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Compliance with EV Guidelines
Oregon Order 12-013 Guideline 2015 IRP
Guideline 1: Forecast the Demand for Flexible Capacity.
Forecast the Demand for Flexible Capacity: The electric utilities shall forecast the balancing reserves needed at different time
intervals (e.g. ramping needed within 5 minutes) to respond to variation in load and intermittent renewable generation over the 20-year planning period;
A discussion of the 2015 IRP’s analysis for the flexibility guideline is provided in Chapter 9 (Modeling Analysis and Results), section Flexible Resource Needs Assessment, pages 135–139. Figure 9.4 on
page 135 presents a projection for flexibility need across multiple timescales. Simulations of the system capability to provide flexibility are illustrated in Figures 9.5 through 9.9 on pages 136–138.
Guideline 2: Forecast the Supply for Flexible Capacity.
Forecast the Supply of Flexible Capacity: The electric utilities shall forecast the balancing reserves available at different time intervals (e.g. ramping available within 5 minutes) from existing generating resources over the 20-year planning period;

Guideline 3: Evaluate Flexible Resources on a Consistent and Comparable Basis
In planning to fill any gap between the demand and supply of flexible capacity, the electric utilities shall evaluate all resource options, including the use of EVs, on a consistent and comparable basis.

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STATE OF OREGON ACTION ITEMS REGARDING IDAHO POWER’S
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Compliance with State of Oregon IRP Guidelines
A. Transmission
1. Boardman to Hemingway
Commission Resolution (Order No. 14-253):
We acknowledge ongoing permitting, planning studies, and regulatory filings for B2H. As Staff notes,
the analysis in the IRP supports these planned near-term activities. We anticipate additional analysis
regarding B2H in Idaho Power's 2015 IRP before acknowledging other actions related to B2H. We decline to acknowledge completion of B2H because it is well beyond the two-to-four year period for
action items specified by the IRP Guidelines. Further, we disagree with any suggestion that declining to
acknowledge the construction of B2H is inconsistent with our previous acknowledgment of certain
activities (e.g., permitting) related to this resource or inconsistent with previous orders acknowledging
IRPs based on a preferred portfolio that includes B2H. Our acknowledgment of an IRP is based on our conclusion that it complies with our guidelines and that the plan seems reasonable based on information
known at the time.
Idaho Power Response (2015 IRP):
Discussion specific to B2H is found in Chapter 6 (Transmission Planning), section Boardman to Hemingway, pages 71-72. Portfolio design for the 2015 IRP provides a comparison of portfolios having
B2H as a resource to portfolios not having B2H. A tabulation of resource portfolios with respect to B2H
inclusion is provided in Chapter 8 (Portfolio Selection), section Portfolio Design Summary, page 111.
2. Gateway West
Commission Resolution (Order No. 14-253):
We acknowledge ongoing permitting, planning studies, and regulatory filings for Gateway West.
However, as CUB notes, the project is composed of multiple segments that can and should be analyzed
individually. Moreover, Idaho Power has an ownership interest in relatively few of the segments and must demonstrate the need and specific constraint-related benefits for each segment in which it holds an interest before we will consider acknowledgment of the project's construction.
Idaho Power Response (2015 IRP):
Discussion specific to Gateway West is found in Chapter 6 (Transmission Planning), pages 69–71. The results of a “need” analysis are provided in the section Gateway West Need Analysis, pages 70–71.
B. Pollution Control Investments in Coal Resources
1. Idaho Power’s Analysis
Commission Resolution (Order No. 14-253):
We conclude that Idaho Power's IRP complies with IRP Guideline 8, but as discussed below, is not
sufficient to provide a basis to support acknowledgment of selective catalytic reduction emission-control technology (SCR) at Jim Bridger units 3 and 4. Guideline 8 does not require Idaho Power to model
every feasible alternative scenario, but requires the company to determine the PVRR costs and risk
measures of a "set of reasonable alternative portfolios" assuming a range of different compliance
scenarios. Although Idaho Power did not model a scenario in which both North Valmy units and Bridger
units 3 and 4 were converted to natural gas facilities, as RNW believes should have been done, Idaho Power did model a scenario in which North Valmy is converted to natural gas and Bridger units 3 and 4
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are replaced with CCCTs (portfolio 6). In addition, although Idaho Power did not build a compliance
scenario that specifically accounts for the June 2013 Presidential Memorandum, Idaho Power did test its
portfolios against a range of carbon compliance futures including a carbon adder in the planning case of
$14.64 per ton beginning in 2018 and escalating three percent annually, and a carbon adder in the high case of $35 per ton beginning in 2018 and escalating nine percent annually.
The carbon adder was modeled at three levels: low ($0), planning, and high. Idaho Power did not model
a distribution of values, as was done with gas prices, load, and hydro in the stochastic analysis. Instead,
one-third of the simulations were drawn from each carbon adder level. The company's analysis showed
the preferred portfolio 2 and the non-coal portfolio 6 would switch places at a carbon adder of $45 in 2018. We find the alternative portfolios selected by Idaho Power and the range of compliance futures
sufficient to satisfy the requirements of Guideline 8.
We share CUB's and Staff’s concern regarding the limited nature of Idaho Power's early retirement
scenario analysis. Even though Idaho Power may have technically complied with the action item from
Order No. 12-177, we expected that Idaho Power would model a broader range of early shutdown scenarios. We expect Idaho Power to engage fully with Staff and stakeholders in a timely manner to
design coal investment analyses for future IRPs to ensure more robust consideration of early shutdown
as a compliance option.
Also, we direct Idaho Power to work with stakeholders to explore options for how it plans to model and
perform analysis in the 2015 IRP in order to comply with the applicable emissions requirements of Section 111(d) of the Clean Air Act.
Idaho Power Response (2015 IRP):
The 2015 IRP considers multiple early retirement scenarios as described in Chapter 8 (Portfolio
Selection), pages 97–111. These early retirement scenarios were developed with input from the IRP Advisory Council and public participants of the IRP process, including input received at a portfolio
design workshop held on January 28, 2015.
CAA Section 111(d) was discussed frequently during IRP Advisory Council meetings. A discussion led
by IRP Advisory Council member John Chatburn (Idaho Office of Energy Resources) was held as part
of the December 4, 2014 IRP Advisory Council meeting. Multiple sensitivities for CAA Section 111(d) were analyzed for the IRP. These sensitivities are described in Chapter 9 (Modeling Analysis and
Results), section CAA Section 111(d) Sensitivity Analysis, pages 114–120.
2. North Valmy Unit 1
Commission Resolution (Order No. 14-253):
We acknowledge installation of DSI at North Valmy Unit 1. We find as Staff did that the relatively low
cost of the investment leads to the conclusion that the DSI investment and continued operation of North
Valmy is the least cost/least risk alternative given the information that is currently available.
We do not share CUB's concern regarding how Idaho Power included North Valmy in its preferred portfolio. First, shortening the life of North Valmy would not change the result of Idaho Power's
analysis; installing DSI would still be the least cost/least risk alternative. Second, future events may lead
to a shortened operating life for North Valmy, but whether they will is not certain. Idaho Power
reasonably relied on the results of modeling based on the assumption North Valmy will operate as Idaho
Power currently expects, rather than an assumption based on events that may, or may not, transpire.
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Idaho Power Response (2015 IRP):
No action required.
3. Jim Bridger Units 3 and 4
Commission Resolution (Order No. 14-253):
Based on the information we have at this time, we decline to acknowledge Idaho Power's action item
related to Bridger units 3 and 4. Our decision regarding these investments is inextricably tied to our decision regarding the same investments in the docket opened to address PacifiCorp's IRP, docket LC 57. In that docket, we did not acknowledge the investments for Bridger units 3 and 4 for four interrelated
reasons.
First, some of the alternatives modeled by PacifiCorp suggest that the installation of SCR at Bridger
units 3 and 4 is not the lowest cost resource option. Second, there were gaps in the analyses conducted by PacifiCorp. Third, some of the questions raised by Staff and other participants on the merit of retaining or retiring the units were not fully fleshed out, while others are more appropriately addressed
in a rate proceeding. Finally, PacifiCorp, the managing utility, is proceeding with the investments, which
calls into question the appropriateness of addressing the investments in a planning docket.
We recognize that Idaho Power conducted its own analysis of whether installing SCR at Bridger units 3 and 4 is the least cost and least risk option. However, Idaho Power's analysis does not persuade us to reach a resolution in this docket that differs from that in docket LC 57, at least in part because of
deficiencies in Idaho Power's analysis. More specifically, Idaho Power did not (1) analyze a full range of
reasonable scenarios; (2) consider a wider range of resource replacement options as PacifiCorp; or (3)
evaluate an adequate range of natural gas price sensitivities.
Idaho Power is proceeding with the investments. We will undertake a fair and thorough investigation of
the prudence of the SCR investments when Idaho Power seeks rate recovery. Our decision to not
acknowledge them in this docket does not prejudge the prudence of the investments for purposes of rate
recovery.
Idaho Power Response (2015 IRP):
A section titled Jim Bridger units 3 and 4 SCR Analysis is included in Appendix C—
Technical Appendix.
C. Demand Response
Commission Resolution (Order No. 14-253):
We agree that revising the near-term demand response action item as recommended by Staff is appropriate in light of recently concluded dockets in Oregon and Idaho regarding demand response. We
acknowledge the action item as revised by Staff. We also expect that Idaho Power will follow Staff’s
recommendation regarding updating its assessment of demand response availability in 2014.
Idaho Power Response (2015 IRP):
The performance of demand response programs in 2014 is provided in Chapter 4 (Demand-Side Resources), section Demand Response Performance, pages 42–43. Chapter 4 also notes that demand
response is forecast to provide 390 MW of peak reduction during July throughout the planning period
(section Committed Demand Response, page 46).
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D. Long-Term Action Items
Commission Resolution (Order No. 14-253):
Although Idaho Power states it does not seek acknowledgment of these long-term action items, they
remain part of the company's IRP. For this reason, we believe it is necessary to address them. We do not
acknowledge these action items because, as Staff and CUB note, the purpose of an action plan is to identify specific near-term actions that the company plans to take to meet its resource needs. We generally do not acknowledge action items planned to occur more than four years in the future.
Idaho Power Response (2015 IRP):
The action plan provided in the 2015 IRP is focused on resource actions for the four-year period 2015-
2018. The action plan is provided in Chapter 1 (Summary), section Action Plan, page 10–11. The action plan is also provided in Chapter 10 (Action Plan), section Action Plan (2015–2018), pages 141–143.
E. Analysis of IRP
1. Wind Resources
Commission Resolution (Order No. 14-253):
We appreciate that Idaho Power responded quickly to our recommendation but are disappointed the TRC did not prove to be an effective mechanism for stakeholders to engage with Idaho Power regarding the analytical methodology of the WIS. Using the TRC to review and provide comments on the
analytical methodology and results is not what we envisioned when making our 2012 recommendation.
But, we recognize that our recommendation came late in Idaho Power's process, limiting the opportunity
for TRC input.
We continue to recommend use of a TRC in connection with wind integration studies. The TRC could be an effective mechanism for stakeholders to engage with the company regarding the analytical
methodology underlying the study and expect Idaho Power to engage with the TRC at the outset of any
future study.
Regarding RNW's specific complaints regarding the WIS, we note that RNW does not urge us to disregard the WIS for the purpose of judging the reasonableness of Idaho Power's IRP, but cautions against using the WIS to determine avoided cost prices in a future proceeding. Our acknowledgment of
Idaho Power's IRP has no effect on the validity of the WIS during any proceeding to establish avoided
cost prices for variable wind resources. We do note, however, that effective engagement between
stakeholders and utilities regarding the study methodology and inputs would likely lessen disagreements in any proceeding in which the accuracy of the study is at issue.
Idaho Power Response (2015 IRP):
No action required.While no IRP-related action is required, Idaho Power notes the use of a technical
review committee from the outset of its first solar integration study, completed in June 2014. A technical review committee has also been in place since the January 2015 start of Idaho Power’s second solar
integration study.
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2. Capacity Contribution of Solar and Other Resources
Commission Resolution (Order No. 14-253):
We appreciate Idaho Power’s willingness to work on the issues identified by ODOE for its next IRP. We hope Idaho Power will work directly with ODOE. In any event, we expect to see results of Idaho
Power’s work in its 2015 IRP.
Idaho Power Response (2015 IRP):
Idaho Power convened public working group meetings to address solar-related issues, including capacity contribution, on August 6, 2014 and September 3, 2014. The results of the solar capacity contribution
analysis conducted as part of the working group meetings are provided in Chapter 5 (Supply-Side
Generation and Storage Resources), section Solar Capacity Credit, pages 50–51.
3. Gas Price Forecasts
Commission Resolution (Order No. 14-253):
We anticipate these analytical issues will be raised by Staff and addressed during the planning process
for the 2015 IRP.
Idaho Power Response (2015 IRP):
The natural gas price forecast is provided in Chapter 7 (Planning Period Forecasts), section Natural Gas
Price Forecast, pages 84–85. As noted in this section, Idaho Power uses EIA published nominal forecast
prices. Also noted is the use of the EIA high resource case for the low case natural gas price forecast, and similarly use of the EIA low resource case for the high case natural gas price forecast. Finally, part
of AURORA model calibration conducted for the IRP is verification that future power market (i.e., Mid-
C) prices derived by the AURORA model maintain their historic relationship to natural gas market
prices. The ratio of these prices, power market and natural gas market, is called the implied market heat
rate. Idaho Power verified that future implied market heat rate values (ratio of AURORA-derived power market price to input natural gas market price) reasonably approximate historic values for this ratio. The
implied market heat rate analysis was presented to the IRP Advisory Council and public participants at
the February 5, 2015 IRP Advisory Council meeting.
4. Flexibility Guideline
Commission Resolution (Order No. 14-253):
We find that Idaho Power's IRP does not comply with the Flexible Resources Guideline. Idaho Power
did not submit the required analysis of demand and supply of balancing reserves disaggregated across
multiple timescales. We expect the company to use the recommendations of both RNW and Staff to provide a compliant and more robust analysis regarding flexible resources in its 2015 IRP.
Idaho Power Response (2015 IRP):
A discussion of the 2015 IRP’s analysis for the flexibility guideline is provided in Chapter 9 (Modeling
Analysis and Results), section Flexible Resource Needs Assessment, pages 135–139. Figure 9.4 on page 143 presents a projection for flexibility need across multiple timescales. Simulations of the system
capability to provide flexibility are illustrated in Figures 9.5 through 9.9 on pages 136-138.
5. Conservation Voltage Reduction
Commission Resolution (Order No. 14-253):
Staff states that Idaho Power failed to include the required assessment of the available cost effective
conservation voltage reduction (CVR) in its service area. Staff explains that we directed the assessment
in our review of Idaho Power's 2012 IRP:
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The next IRP filed by Idaho Power will include an assessment of the available cost-
effective conservation voltage reduction (CVR) resource potential in its service area. The
company will propose an action item in its 2013 IRP related to this resource. The planned
energy savings and reduced peak demand will be incorporated into Idaho Power's load-resource balance forecasts.
We agree that Idaho Power's 2013 IRP failed to include this assessment, and direct the company to
provide this assessment in its 2015 IRP. In the interim, we direct our Staff to conduct the independent
CVR and Volt/Var Ampere Reactive control programs we ordered in Idaho Power's 2013 Annual Smart
Grid Report. Staff should conduct the analysis within the next six months and report the results of the analysis to us at a public meeting.
Idaho Power Response (2015 IRP):
CVR is discussed in Chapter 4 (Demand-Side Resources), section Conservation Voltage Reduction,
page 48. The 2015 IRP’s treatment of CVR was communicated to OPUC staff in a conference call on August 22, 2014.
6. Energy Efficiency
Commission Resolution (Order No. 14-253):
We adopt Staff’s proposed additions to the Action Plan. [Staff proposed the addition of action plan items specifying IRP energy efficiency targets.]
Idaho Power Response (2015 IRP):
The action plan provided in the 2015 IRP includes an action item related to the pursuit of cost-effective energy efficiency, and expresses energy efficiency targets in a manner similar to that proposed by Staff.
The action plan is provided in Chapter 1 (Summary), section Action Plan, pages 10–11. The action plan
is also provided in Chapter 10 (Action Plan), section Action Plan (2015–2018), pages 141–143.
7. NEEA
Commission Resolution (Order No. 14-253):
We do not know Idaho Power's final decision about continued participation in NEEA. However, we are
dismayed by the possibility that Idaho Power's approach could undermine support for regional market
transformation. We agree with Staff’s observations of the importance of NEEA. We believe that market transformation is an integral part of an effective energy efficiency strategy to lower cost and risk to
ratepayers. Based on our analysis and our continued oversight of funding to NEEA from Oregon
ratepayers, we believe that NEEA is capturing cost-effective energy efficiency over the long run and
expanding opportunities for cost-effective energy efficiency in the future. For those programs Idaho
Power opts out of, we expect Idaho Power will acquire commensurate savings from equivalent services at a cost equal to or less than what NEEA could provide.
Idaho Power Response (2015 IRP):
Idaho Power continues its commitment to NEEA as a participant in NEEA’s 2015-2019 funding cycle. On September 30, 2014 Idaho Power and NEEA executed a contract to participate in the 2015-2019 funding cycle. For complete details on Idaho Power’s involvement in NEEA activities please see pages
9, 141-145 of the Company’s Demand-Side Management 2014 Annual Report – Appendix B.