201307012013 IRP Appendix C Technical Index.PDF

June 2013
Technical Report
2013 Integrated
Resource Plan
APPENDIX C
June 2013
Integrated Resource Plan
ACKNOWLEDGEMENT
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 2013 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
of individuals that represent many different
departments 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.
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.
2013
Printed on recycled paper
Technical Report
APPENDIX C
Idaho Power Company Table of Contents
2013 Integrated Resource Plan—Appendix C Page i
TABLE OF CONTENTS
Table of Contents ............................................................................................................................. i
Introduction ......................................................................................................................................1
IRP Advisory Council ......................................................................................................................2
List of Advisory Council Members ...........................................................................................2
IRP Advisory Council Meeting Schedule and Agenda ..............................................................3
Public Policy Issues .........................................................................................................................5
Greenhouse Gas Emissions ........................................................................................................5
Flow Modeling ...........................................................................................................................8
Sales and Load Forecast Data ........................................................................................................11
Average Annual Forecast Growth Rates..................................................................................11
Expected-Case Load Forecast ..................................................................................................12
70th Percentile Load Forecast ...................................................................................................22
Load and Resource Balance Data ..................................................................................................31
Monthly Average Energy Load and Resource Balance ...........................................................31
Monthly Average Energy Surplus/Deficit Charts ....................................................................52
Peak-Hour Load and Resource Balance ..................................................................................53
Peak-Hour Surplus/Deficit Charts ...........................................................................................73
Demand-Side Resource Data .........................................................................................................74
Cost Effectiveness ....................................................................................................................74
Alternate Costs .........................................................................................................................75
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
Resource Advantages and Disadvantages ................................................................................91
Resource Peak Hour Shape ......................................................................................................93
Capacity Factors for Solar PV .................................................................................................93
Fuel Data ........................................................................................................................................96
Natural Gas and Coal Price Forecast .......................................................................................96
Table of Contents Idaho Power Company
Page ii 2013 Integrated Resource Plan—Appendix C
Existing Resource Data ..................................................................................................................98
Hydroelectric and Thermal Plant Data ....................................................................................98
Qualifying Facility Data (PURPA) ..........................................................................................99
Power Purchase Agreement Data...........................................................................................100
Hydro Modeling Results (PDR580).......................................................................................101
Portfolio Analysis, Results, and Supporting Documentation ......................................................131
Stochastic Dispersion Plot .....................................................................................................131
Regulatory Environmental Compliance Costs .......................................................................131
Loss of Load Expectation Analysis .......................................................................................132
State of Oregon IRP Guidelines ...................................................................................................137
Compliance with State of Oregon IRP Guidelines ................................................................145
State of Oregon IRP Electric Vehicles (EV) Guidelines .............................................................151
Compliance with EV Guidelines ...........................................................................................155
State of Oregon Action Items Regarding Idaho Power’s 2011 IRP ............................................156
Compliance with State of Oregon Action Items Regarding Idaho Power’s 2011 IRP ..........165

Idaho Power Company Introduction
2013 Integrated Resource Plan—Appendix C Page 1
INTRODUCTION
Appendix C–Technical Appendix contains supporting data and explanatory materials used to develop
Idaho Power’s 2013 Integrated Resource Plan (IRP).
The main document, the IRP, contains a full narrative of Idaho Power’s resource planning process.
Additional information regarding the 2013 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 2012 Annual Report. The IRP, including the three appendices,
was filed with the Idaho and Oregon public utility commissions in June 2013.
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 2013 Integrated Resource Plan—Appendix C
IRP ADVISORY COUNCIL
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. The IRP Advisory Council 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 2013 IRP, Idaho Power hosted a field trip covering the distribution and
transmission system and the natural gas power generation. Idaho Power also hosted 11 IRP Advisory Council meetings, including a resource portfolio design workshop. Idaho Power and members from the IRP Advisory Council also met in several small break-out sessions to discuss certain topics in greater
detail. Idaho Power values these opportunities to convene, and the IRP Advisory Council members and
the public have made significant contributions to this plan.
Idaho Power believes working with members of the IRP Advisory Council and the public is very rewarding, and the IRP is better because of the public involvement. Idaho Power and the members of the IRP Advisory Council recognize that outside perspective is valuable, but also recognize that final
decisions on the IRP are made by Idaho Power.
List of Advisory Council Members
Customer Representatives
Agricultural Representative ................................................. Sid Erwin
Boise State University ......................................................... John Gardner
Idaho National Laboratory .................................................. Kurt Myers
Micron ................................................................................. John Velikoff
Simplot ................................................................................ Don Sturtevant
Public Interest Representatives
Boise Metro Chamber of Commerce ................................... Ray Stark
Idaho Conservation League ................................................. Ben Otto
Idaho Department of Commerce ......................................... Gynii Gilliam
Idaho Office of Energy Resources....................................... John Chatburn
Idaho State House of Representatives ................................. Representative Brent Crane
Idaho State Senate ............................................................... Senator Russ Fulcher
Idaho Technology Council .................................................. Jay Larsen
Northwest Power and Conservation Council....................... Shirley Lindstrom
Northwest Power and Conservation Council....................... Jim Yost
Oil and Gas Industry Advisor .............................................. David Hawk
University of Idaho Integrated Design Lab ......................... Kevin Van Den Wymelenberg
Water Issues Advisor ........................................................... Vince Alberdi
Regulatory Commission Representatives
Idaho Public Utilities Commission ...................................... Bryan Lanspery
Public Utility Commission of Oregon ................................. Brittany Andrus
Idaho Power Company IRP Advisory Council
2013 Integrated Resource Plan—Appendix C Page 3
IRP Advisory Council Meeting Schedule and Agenda
Meeting Dates Agenda Items
2012 Thursday, August 16 Background and Process
Explanation of the IRP Process
Summary of 2012 Summer Peak Load Season
Preliminary Resources to Include in the Resource Stack
DSM Potential Study
Recent Transmission Issues
Boardman to Hemingway Update
2012 Thursday, September 6 Thermal Fuels and Associated Issues
Natural Gas Price Forecast and Transportation
Coat and Gas Unit Forecast
Renewable Energy Credit
Carbon Adder and Proposed Federal Legislation
CSPP Forecast
2012 Wednesday, October 10 Field Trip to Langly Gulch and Hemingway Substation
2012 Thursday, October 11 Hydro Resources and Issues, Customer Load
Water Issues
Hydro Forecast
Load Forecast
DSM Program Forecast
2012 Thursday, November 15 2011 IRP Update
Environmental Compliance Cost Study
Boardman to Hemingway Update
Load Forecast
Natural Gas Price Forecast
DSM Update
2012 Friday, November 30 Portfolio Design Workshop
2012 Thursday, December 13 Portfolio Modeling Review
Portfolio Workshop Review
Load and Resource Balance
Resource Cost Summary
Portfolio Modeling Plan
Aurora Model Overview
Conservation Voltage Reduction
2013 Thursday, January 17 Meeting Canceled
2013 Thursday, February 21 2011 IRP Update Filing and Resource Analysis
Coal Study Results
Boardman to Hemingway Update
Preliminary Resource Analysis
Idaho Power Response to Hurricane Sandy
2013 Thursday, March 14 Risk Analysis Methods
Resource Alternatives Risk Analysis
Preliminary Resource Portfolio Analysis
Hells Canyon Relicensing
IRP Advisory Council Idaho Power Company
Page 4 2013 Integrated Resource Plan—Appendix C
Meeting Dates Agenda Items
2013 Thursday, April 11 Risk Analysis Results
Resource Portfolio Risk Analysis
2013 Water Year Projections
DSM Annual Report
2013 Thursday, May 9 Risk Analysis Results (continued)
Questions from the April Meeting Concerning the Resource Portfolio Risk Analysis
Results from the Two Resource Portfolios that Retire the North Valmy Coal Plant
2013 Thursday, June 6 Conclusion
Draft IRP Document
IRP Public Presentation Review
Energy Imbalance Market
Summer 2013 Preparedness

Idaho Power Company Public Policy Issues
2013 Integrated Resource Plan—Appendix C Page 5
PUBLIC POLICY ISSUES
Greenhouse Gas Emissions
Climate Change and the Regulation of Greenhouse Gas Emissions
Overview
Long-term climate change could significantly affect Idaho Power’s business in a variety of
ways, including:
• Changes in temperature and precipitation could affect customer demand and energy loads
• Extreme weather events could increase service interruptions, outages, maintenance costs, and the
need for additional backup systems, and can affect the supply of, and demand for, electricity and
natural gas, which may impact the price of energy commodities
• Changes in the amount and timing of snowpack and stream flows could adversely affect hydroelectric generation
• Legislative and/or regulatory developments related to climate change could affect plants and
operations, including restrictions on the construction of new generation resources, the expansion
of existing resources, or the operation of generation resources in general
• Consumer preference for, and resource planning decisions requiring, renewable or low greenhouse gas (GHG)-emitting sources of energy could impact usage of existing generation
sources and require significant investment in new generation and transmission infrastructure
Some recent initiatives regarding GHG emissions contemplate market-based compliance programs,
such as cap-and-trade programs or emission offsets. However, the regulation of GHG emissions under the CAA could result in GHG emission limits on stationary sources that do not provide market-based
compliance options. Such a program could raise uncertainty about the future viability of fossil fuels,
specifically coal, as an economical energy source for new and existing electric generation facilities
because many new technologies for reducing CO2 emissions from coal, including carbon capture and
storage, are still in the development stage and are not yet proven. Emission standards could require significant increases in capital expenditures and operating costs, which may accelerate the retirement of
coal-fired units. Due in part to the uncertainty of future GHG regulations, in its 2011 IRP Idaho Power
did not include any new conventional coal resources in its resource portfolios.
A variety of factors contribute to the financial, regulatory, and logistical uncertainties related to GHG
reductions, including the specific GHG emissions limits, the timing of implementation of these limits, the level of emissions allowances allocated and the level that must be purchased, the purchase price of
emissions allowances, the development and commercial availability of technologies for renewable
energy and for the reduction of emissions, the degree to which offsets may be used for compliance,
provisions for cost containment (if any), the impact on coal and natural gas prices, and cost recovery
through rates. Accordingly, Idaho Power cannot predict the effect on its results of operations, financial position, or cash flows of any GHG emission or other global climate change requirements that may be
Public Policy Issues Idaho Power Company
Page 6 2013 Integrated Resource Plan—Appendix C
adopted, although the costs to implement and comply with any such requirements could be substantial.
A more detailed discussion of legislative and regulatory developments related to climate change follows.
National and International GHG Initiatives
There is concern both nationally and internationally about climate change and the possible contribution of GHG emissions to climate change. In support of international efforts to reduce GHG emissions,
in January 2010 the Obama Administration pledged to cut GHG emissions in the United States from
2005 levels by 17 percent by 2020 and 80 percent by 2050. Other communications from the Obama
Administration have proposed the adoption of a clean energy standard in the U.S., calling for 80 percent
of American energy to come from clean sources by 2035. Further, climate change regulation has been a recent priority of the U.S. Congress. In prior legislative sessions, legislation in both the U.S. House and
Senate was introduced to enact a comprehensive climate change program, but these attempts were
unsuccessful. At the same time, legislation has also been introduced seeking to amend the CAA to
prohibit the EPA from promulgating regulations on the emissions of GHGs to address climate change
and excluding GHGs from the definition of an "air pollutant" for purposes of addressing climate change. Neither areas of focus have culminated in legislation and have led to greater uncertainty as to the
direction of GHG regulation.
At the same time, the EPA has become increasingly active in the regulation of GHGs. The EPA’s
endangerment finding in 2009 that GHGs threaten public health and welfare resulted in enactment of a
series of EPA regulations to address GHG emissions. The EPA has issued final rules regulating GHG emissions under the New Source Review (NSR)/Prevention of Significant Deterioration (PSD)
and Title V Operating Permit programs under the CAA. Specifically, in May 2010 the EPA issued the
“Tailoring Rule,” which set thresholds for GHG emissions that define when permits are required for new
and existing industrial facilities. The final rule “tailors” the requirements of these CAA permitting
programs to limit which facilities will be required to obtain PSD and Title V permits. Additionally, in December 2010 the EPA issued a series of final regulations for GHG emissions designed to ensure
that industrial facilities can obtain CAA permits for GHG emissions, and that facilities emitting GHGs at
levels below those established in the Tailoring Rule do not need federal CAA permits. The first phase of
the rules took effect in January 2011 and required imposition of Best Available Control Technology
(BACT) for GHG emissions if a new major source or modification of an existing major source is projected to result in GHG emissions of at least 75,000 tons per year (CO2 equivalent). In addition,
Title V permit renewals or modifications for existing major sources must include applicable
requirements relating to GHGs. Lawsuits opposing EPA's endangerment finding and Tailoring Rule
were unsuccessful. While the rules are complex, Idaho Power believes that its owned and co-owned
generation plants are, as of the date of this report, in compliance with the new GHG Tailoring Rules.
In addition, in April 2012, the EPA proposed New Source Performance Standards (NSPS) limiting CO2 emissions from new electric utility generating units (EGUs) fired by fossil fuels. The proposed
requirements, which are limited to new sources, would require new fossil fuel-fired EGUs greater than
25 MW to meet an output-based standard of 1,000 pounds of CO2 per MWh. The EPA did not propose
standards of performance for existing EGUs whose CO2 emissions increase as a result of installation of pollution controls for conventional pollutants. While Idaho Power does not expect the new NSPS to
impact its existing generation facilities, if promulgated the new rule would impact the cost effectiveness
of developing new generation units.
Idaho Power Company Public Policy Issues
2013 Integrated Resource Plan—Appendix C Page 7
State and Regional GHG Initiatives
On a regional level, there are a number of initiatives, including the Western Regional Climate Action
Initiative, considering market-based mechanisms to reduce GHG emissions. Separately, in August 2007
the Oregon legislature enacted legislation setting goals of reducing GHG levels to 10 percent below 1990 levels by 2020 and at least 75 percent below 1990 levels by 2050. Oregon imposes GHG emission
reporting requirements on facilities emitting 2,500 metric tons or more of CO2 equivalent annually.
The mechanism was implemented in two phases, with Title V sources and entities with an air discharge
permit required to start reporting 2009 emissions in 2010 and all other sources required to start reporting
2010 emissions in 2011. The Boardman coal-fired power plant, in which Idaho Power is a 10-percent owner, is subject to and in compliance with Oregon's GHG reporting requirements.
The State of Idaho has not passed legislation specifically regulating GHGs, but in May 2007 Governor
Otter issued Executive Order 2007-05, which directed the Idaho Department of Environmental Quality
to work with the state government to implement GHG reductions within each agency, complete a
statewide emissions inventory, and provide recommendations to the Governor, among other tasks. Wyoming and Nevada similarly have not enacted legislation to regulate GHG emissions and do not have
a reporting requirement, but are members of the Climate Registry, a national, voluntary GHG emission
reporting system. The Climate Registry is a collaboration aimed at developing and managing a common
GHG emission reporting system across states, provinces, and tribes to track GHG emissions nationally.
All states for which Idaho Power has traditional fuel plants operating (i.e., Idaho, Oregon, Wyoming, and Nevada) are members of the Climate Registry.
Idaho Power's Voluntary GHG Reduction Initiatives
Despite the current absence of a national mandatory GHG reduction program, Idaho Power is engaged in
voluntary GHG emission intensity reduction efforts. Also, Idaho Power has voluntarily submitted
information to the Carbon Disclosure Project, an independent, not-for-profit organization that claims the largest database of corporate climate change information in the world. Idaho Power's estimated CO2
emission intensity (lbs/MWh) from its generation facilities as submitted to the Carbon Disclosure
Project was 672, 1,051, 1,004, 1,097, and 1,150 lbs/MWh for 2011, 2010, 2009, 2008, and 2007,
respectively.
In 2010, Idaho Power and Ida-West together ranked as the 37th lowest emitter of CO2 per MWh produced and the 35th lowest emitter of CO2 by tons of emissions among the nation’s 100 largest
electricity producers, according to a July 2012 collaborative report from Ceres, the Natural Resources
Defense Council, and other entities using publicly reported 2010 generation and emissions data.
According to the report, out of the 100 companies named, Idaho Power and Ida-West together ranked as
the 58th largest power producer based on fossil fuel, nuclear, and renewable energy facility total electricity generation.
Public Nuisance-Related Suits for GHGs
In June 2011, the U.S. Supreme Court held that federal courts do not have jurisdiction to hear federal
common law nuisance claims relating to GHG emissions because the legal authority to regulate GHGs
has been delegated by Congress to the EPA, not to federal courts. The Court did not address, however, whether state common law nuisance claims would also be barred by the federal CAA. Accordingly,
the Supreme Court’s decision did not completely eliminate the potential for future nuisance-related suits
for GHG emissions.
Public Policy Issues Idaho Power Company
Page 8 2013 Integrated Resource Plan—Appendix C
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 recently updated in late 2012 to include
hydrologic conditions for years 1928 through 2009. ESPAM was also recently updated with the release
of ESPAM 2.0 in July 2012. Subsequent to the completion of the modeling for the 2013 IRP, a corrected version ESPAM 2.1 was released in late 2012. The ESPAM 2.1 update corrected issues discovered within the model in locations in the Snake River basin above Idaho Falls, Idaho. After reviewing output
from the updated version of ESPAM, it was determined that the corrections would have no significant
impact on the modeling that had been performed for the 2013 IRP.
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.
Idaho Power completed an update to the combined model for the 2013 IRP.
Model Inputs
The model inputs used in this effort are similar to the inputs used in the 2009 and 2011 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 Dan demonstrated a
statistically significant decline for the period of 1981 to 2011. Both reaches declined on average
29 cubic feet per second per month (cfs/month) with declines ranging from 25 to 35 cfs/month for American Falls and 18 to 39 cfs/month for Milner to Lower Salmon Falls. 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 two different levels of development. The existing level
of development was added to the model for IRP years 2013 and 2014. For IRP years 2015 and beyond,
weather modification was increased to reflect a projected level of a fully built-out program in Eastern Idaho. The amount of weather modification added to each year is 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 224,000 acre feet per year (acft/year) and the Upper Snake Basin adds an average of
410,000 acft/year.
Aquifer recharge was added to the model at levels reflected in the 2009 Comprehensive Aquifer Management Plan (CAMP) and the recharge limits included in the Swan Falls Reaffirmation agreement.
Nine recharge diversions were modeled across the ESPA with a total maximum diversion of 1,315 cfs.
Recharge peaks in IRP year 2019 at approximately 200,000 acft and then slowly declines as diminishing
reach gains limit the amount of water available for aquifer recharge.
Idaho Power Company Public Policy Issues
2013 Integrated Resource Plan—Appendix C Page 9
CAMP targeted a level of system conversion where ground water supplied irrigated land is converted 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. The current model assumes a total of
13,683 acres of converted land on the ESPA with a total water savings of 1.4 acft or water per acre of irrigated land (acft/ac), and a maximum of 19,156 acft/year. This number is not solely based on the
number of acres idled but also on available water to meet irrigation requirements. The modeled data
show conversions reach a peak water savings of 17,600 acft in IRP year 2015. Subsequent reach
declines reduce water available for system conversions. In IRP year 2027, water savings declined to
17,100 acft.
The model accounts for approximately 15,410 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 acft/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.
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 2013 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 2013 through 2015 in response to increased weather modification in the Upper Snake River Basin. Flows peak in 2015 with
the 50 percent exceedance flows into Brownlee Reservoir as just over 11.5 Million acft/year. In 2027,
those flows have declined to approximately 11.25 Million acft/year, with most of the declines
attributable to spring discharge in the Milner to Lower Salmon Falls reach.

Public Policy Issues Idaho Power Company
Page 10 2013 Integrated Resource Plan—Appendix C
2013 Model Parameters
Managed Recharge (acft/yr) Weather Modification (acft/yr) Lease Water Reach Declines (acft/yr)
IRP Year
Above American Falls
Below American Falls Snake River Basin Payette Basin
System Conversions (Ac) CREP (Ac) 740 cfs in August
American Falls Inflows Below Milner
2013 54,500 48,400 124,000 224,000 13,683 16,684 Yes 82,671 84,535
2014 66,600 48,400 124,000 224,000 13,683 16,684 Yes 103,338 105,669
2015 66,600 90,800 410,000 224,000 13,683 16,684 Yes 124,006 126,803
2016 66,600 90,800 410,000 224,000 13,683 16,684 No 144,673 147,937
2017 66,600 108,900 410,000 224,000 13,683 16,684 No 165,340 169,071
2018 88,200 115,000 410,000 224,000 13,683 16,684 No 186,007 190,205
2019 88,200 122,100 410,000 224,000 13,683 16,684 No 206,674 211,339
2020 88,200 122,100 410,000 224,000 13,683 16,684 No 227,341 232,473
2021 88,200 122,100 410,000 224,000 13,683 16,684 No 248,008 253,607
2022 88,200 122,100 410,000 224,000 13,683 12,513 No 268,675 274,741
2023 88,200 122,100 410,000 224,000 13,683 8,342 No 289,342 295,875
2024 88,200 122,100 410,000 224,000 13,683 4,171 No 310,009 317,009
2025 88,200 122,100 410,000 224,000 13,683 0 No 330,676 338,143
2026 88,200 122,100 410,000 224,000 13,683 0 No 351,343 359,277
2027 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411
2028 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411
2029 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411
2030 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411
2031 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411
2032 88,200 122,100 410,000 224,000 13,683 0 No 372,010 380,411

Idaho Power Company Sales and Load Forecast Data
2013 Integrated Resource Plan—Appendix C Page 11
SALES AND LOAD FORECAST DATA
Average Annual Forecast Growth Rates
2013–2018 2013–2023 2013–2032
Sales
Residential Sales ............................................................................................... 1.07% 1.09% 1.08%
Commercial Sales.............................................................................................. 1.09% 1.07% 1.10%
Irrigation Sales ................................................................................................... 0.05% 0.07% 0.01%
Industrial Sales .................................................................................................. 2.25% 1.95% 1.71%
Additional Firm Sales ......................................................................................... 0.97% 2.03% 1.16%
System Sales ..................................................................................................... 1.15% 1.18% 1.08%
Total Sales ......................................................................................................... 1.15% 1.18% 1.08%
Loads
Residential Load ................................................................................................ 1.08% 1.09% 1.08%
Commercial Load............................................................................................... 1.08% 1.07% 1.10%
Irrigation Load .................................................................................................... 0.05% 0.07% 0.00%
Industrial Load ................................................................................................... 2.23% 1.94% 1.69%
Additional Firm Sales ......................................................................................... 0.97% 2.03% 1.16%
System Load Losses ......................................................................................... 1.08% 1.08% 1.03%
System Load ...................................................................................................... 1.14% 1.17% 1.07%
Total Load .......................................................................................................... 1.14% 1.17% 1.07%
Peaks
System Peak ..................................................................................................... 1.54% 1.52% 1.41%
Total Peak ......................................................................................................... 1.54% 1.52% 1.41%
Winter Peak ....................................................................................................... 0.81% 0.90% 0.82%
Summer Peak .................................................................................................... 1.54% 1.52% 1.41%
Customers
Residential Customers ....................................................................................... 1.82% 1.68% 1.47%
Commercial Customers ..................................................................................... 1.94% 1.81% 1.59%
Irrigation Customers .......................................................................................... 1.30% 1.26% 1.20%
Industrial Customers .......................................................................................... 1.18% 1.15% 0.99%

Sales and Load Forecast Data Idaho Power Company
Page 12 2013 Integrated Resource Plan—Appendix C
Expected-Case Load Forecast
Monthly Summary1 1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013
Average Load (aMW)–50th Percentile
Residential .......................... 792 670 567 487 442 467 589 566 461 457 580 806
Commercial ......................... 487 444 415 397 403 429 504 491 435 406 428 505
Irrigation .............................. 2 2 2 72 298 524 643 502 295 43 0 1
Industrial .............................. 264 266 262 251 254 270 269 273 270 274 273 278
Additional Firm .................... 118 116 113 115 110 112 116 116 112 112 120 122
Loss ..................................... 164 146 131 128 148 180 214 195 155 124 135 169
System Load ................... 1,828 1,644 1,491 1,451 1,655 1,982 2,336 2,143 1,728 1,416 1,537 1,882
Light Load ........................... 1,688 1,517 1,370 1,314 1,505 1,774 2,119 1,901 1,553 1,277 1,418 1,738
Heavy Load ......................... 1,938 1,739 1,586 1,550 1,774 2,149 2,506 2,317 1,882 1,516 1,632 2,005
Total Load ........................ 1,828 1,644 1,491 1,451 1,655 1,982 2,336 2,143 1,728 1,416 1,537 1,882
Peak Load (MW)–90th Percentile
System Peak (1 hour) ......... 2,445 2,328 2,024 1,956 2,775 3,215 3,344 3,015 2,756 2,013 2,199 2,585
Total Peak Load .............. 2,445 2,328 2,024 1,956 2,775 3,215 3,344 3,015 2,756 2,013 2,199 2,585

Monthly Summary1 1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014
Average Load (aMW)–50th Percentile
Residential .......................... 796 671 569 489 445 472 595 571 465 459 582 810
Commercial ......................... 494 449 421 403 409 436 512 499 443 412 435 512
Irrigation .............................. 2 2 2 72 300 528 647 505 296 43 0 1
Industrial .............................. 272 274 269 259 261 277 277 281 278 282 281 286
Additional Firm .................... 121 117 115 117 113 110 118 118 114 114 122 124
Loss ..................................... 166 148 133 129 150 182 217 198 157 125 137 170
System Load ................... 1,850 1,661 1,510 1,470 1,678 2,004 2,366 2,172 1,754 1,436 1,558 1,903
Light Load ........................... 1,709 1,533 1,387 1,331 1,525 1,794 2,147 1,927 1,575 1,295 1,437 1,758
Heavy Load ......................... 1,962 1,757 1,606 1,571 1,798 2,173 2,539 2,365 1,896 1,538 1,664 2,017
Total Load ........................ 1,850 1,661 1,510 1,470 1,678 2,004 2,366 2,172 1,754 1,436 1,558 1,903
Peak Load (MW)–90th Percentile
System Peak (1 hour) ......... 2,474 2,346 2,047 1,981 2,822 3,261 3,403 3,059 2,800 2,034 2,222 2,606
Total Peak Load .............. 2,474 2,346 2,047 1,981 2,822 3,261 3,403 3,059 2,800 2,034 2,222 2,606

Monthly Summary1 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)–50th Percentile
Residential .......................... 796 669 568 490 446 474 599 575 466 460 583 817
Commercial ......................... 498 452 424 407 413 441 517 504 448 416 438 517
Irrigation .............................. 2 2 2 73 301 530 649 507 298 43 0 1
Industrial .............................. 279 281 277 265 268 285 285 288 286 290 289 293
Additional Firm .................... 124 121 119 120 116 113 121 121 117 117 126 128
Loss ..................................... 167 148 134 130 151 183 219 199 158 127 138 172
System Load ................... 1,866 1,673 1,524 1,485 1,695 2,025 2,390 2,194 1,773 1,452 1,574 1,928
Light Load ........................... 1,723 1,544 1,400 1,345 1,541 1,812 2,168 1,947 1,593 1,310 1,453 1,781
Heavy Load ......................... 1,979 1,770 1,621 1,587 1,827 2,180 2,564 2,389 1,917 1,555 1,681 2,044
Total Load ........................ 1,866 1,673 1,524 1,485 1,695 2,025 2,390 2,194 1,773 1,452 1,574 1,928
Peak Load (MW)–90th Percentile
System Peak (1 hour) ......... 2,471 2,357 2,040 1,965 2,867 3,296 3,456 3,093 2,835 2,053 2,222 2,620
Total Peak Load .............. 2,471 2,357 2,040 1,965 2,867 3,296 3,456 3,093 2,835 2,053 2,222 2,620
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 13
Monthly Summary1 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)–50th Percentile
Residential .......................... 805 675 574 495 452 481 610 585 474 465 590 831
Commercial ......................... 503 457 429 411 417 446 523 510 454 421 443 523
Irrigation .............................. 2 2 2 72 298 524 643 502 294 43 0 1
Industrial .............................. 286 278 283 272 274 291 291 295 292 296 296 298
Additional Firm .................... 124 117 119 120 116 113 121 121 117 117 126 128
Loss ..................................... 169 149 135 132 152 185 220 201 160 128 140 175
System Load ................... 1,889 1,676 1,542 1,502 1,710 2,041 2,408 2,214 1,791 1,471 1,595 1,955
Light Load ........................... 1,745 1,547 1,417 1,361 1,554 1,826 2,185 1,964 1,609 1,327 1,472 1,806
Heavy Load ......................... 2,014 1,772 1,632 1,606 1,844 2,197 2,600 2,394 1,937 1,585 1,694 2,073
Total Load ........................ 1,889 1,676 1,542 1,502 1,710 2,041 2,408 2,214 1,791 1,471 1,595 1,955
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,486 2,370 2,050 1,971 2,906 3,323 3,500 3,121 2,867 2,070 2,235 2,640
Total Peak Load .............. 2,486 2,370 2,050 1,971 2,906 3,323 3,500 3,121 2,867 2,070 2,235 2,640

Monthly Summary1 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)–50th Percentile
Residential .......................... 818 683 582 503 460 491 623 597 483 473 600 845
Commercial ......................... 507 460 433 415 421 451 529 516 459 426 447 528
Irrigation .............................. 2 2 2 72 298 524 642 501 294 42 0 1
Industrial .............................. 291 293 288 276 279 297 296 300 298 302 301 303
Additional Firm .................... 125 122 120 121 117 114 122 122 118 118 127 129
Loss ..................................... 171 152 137 134 154 187 223 203 162 130 142 177
System Load ................... 1,915 1,711 1,562 1,522 1,729 2,063 2,435 2,240 1,814 1,491 1,617 1,982
Light Load ........................... 1,768 1,579 1,435 1,378 1,572 1,847 2,209 1,987 1,629 1,345 1,492 1,831
Heavy Load ......................... 2,041 1,810 1,653 1,636 1,853 2,222 2,629 2,422 1,961 1,606 1,718 2,112
Total Load ........................ 1,915 1,711 1,562 1,522 1,729 2,063 2,435 2,240 1,814 1,491 1,617 1,982
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 Summary1 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)–50th Percentile
Residential .......................... 829 690 589 510 467 500 635 609 491 479 608 858
Commercial ......................... 511 463 436 418 425 456 534 520 464 430 451 533
Irrigation .............................. 2 2 2 72 299 526 644 503 295 43 0 1
Industrial .............................. 296 297 293 281 284 301 301 305 302 307 306 308
Additional Firm .................... 125 121 119 121 117 114 122 122 118 118 127 128
Loss ..................................... 173 153 139 135 156 189 225 206 164 131 143 180
System Load ................... 1,936 1,726 1,578 1,538 1,747 2,085 2,461 2,265 1,834 1,508 1,635 2,007
Light Load ........................... 1,788 1,593 1,450 1,393 1,588 1,866 2,233 2,009 1,648 1,360 1,509 1,854
Heavy Load ......................... 2,052 1,826 1,670 1,654 1,872 2,245 2,657 2,449 1,997 1,615 1,737 2,139
Firm Off-System Load ......... 0 0 0 0 0 0 0 0 0 0 0 0
Total Load ........................ 1,936 1,726 1,578 1,538 1,747 2,085 2,461 2,265 1,834 1,508 1,635 2,007
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,536 2,402 2,088 2,009 2,993 3,400 3,609 3,199 2,944 2,107 2,279 2,691
Total Peak Load .............. 2,536 2,402 2,088 2,009 2,993 3,400 3,609 3,199 2,944 2,107 2,279 2,691
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 2013 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 2013 Integrated Resource Plan—Appendix C
Monthly Summary1 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)–50th Percentile
Residential .......................... 839 696 595 517 474 508 646 619 498 485 616 868
Commercial ......................... 516 466 440 422 429 461 539 526 470 434 455 538
Irrigation .............................. 2 2 2 72 300 527 646 504 296 43 0 1
Industrial .............................. 301 303 298 286 288 306 306 310 307 312 311 313
Additional Firm .................... 126 122 120 122 117 115 123 123 119 119 128 129
Loss ..................................... 175 154 140 136 157 191 228 208 166 133 145 182
System Load ................... 1,958 1,742 1,595 1,555 1,765 2,107 2,488 2,291 1,856 1,526 1,655 2,032
Light Load ........................... 1,808 1,608 1,466 1,409 1,605 1,886 2,258 2,032 1,667 1,376 1,527 1,877
Heavy Load ......................... 2,076 1,843 1,697 1,662 1,892 2,284 2,670 2,477 2,021 1,634 1,758 2,165
Total Load ........................ 1,958 1,742 1,595 1,555 1,765 2,107 2,488 2,291 1,856 1,526 1,655 2,032
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,560 2,418 2,107 2,028 3,036 3,439 3,664 3,239 2,983 2,126 2,301 2,716
Total Peak Load .............. 2,560 2,418 2,107 2,028 3,036 3,439 3,664 3,239 2,983 2,126 2,301 2,716

Monthly Summary1 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)–50th Percentile
Residential .......................... 846 699 600 521 478 515 656 628 504 490 622 878
Commercial ......................... 521 470 444 427 434 466 545 532 476 439 459 544
Irrigation .............................. 2 2 2 72 301 528 648 506 297 43 0 1
Industrial .............................. 306 297 303 290 293 312 312 315 313 317 316 318
Additional Firm .................... 132 124 126 127 122 119 127 128 123 124 134 136
Loss ..................................... 177 155 142 138 159 193 230 210 167 135 147 184
System Load ................... 1,984 1,746 1,616 1,576 1,787 2,133 2,517 2,319 1,880 1,547 1,678 2,061
Light Load ........................... 1,832 1,612 1,485 1,428 1,625 1,909 2,284 2,058 1,689 1,395 1,548 1,904
Heavy Load ......................... 2,103 1,846 1,719 1,685 1,927 2,297 2,701 2,525 2,033 1,657 1,792 2,185
Total Load ........................ 1,984 1,746 1,616 1,576 1,787 2,133 2,517 2,319 1,880 1,547 1,678 2,061
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,588 2,436 2,129 2,048 3,084 3,481 3,722 3,281 3,024 2,148 2,326 2,745
Total Peak Load .............. 2,588 2,436 2,129 2,048 3,084 3,481 3,722 3,281 3,024 2,148 2,326 2,745

Monthly Summary1 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)–50th Percentile
Residential .......................... 829 690 589 510 467 500 635 609 491 479 608 858
Commercial ......................... 511 463 436 418 425 456 534 520 464 430 451 533
Irrigation .............................. 2 2 2 72 299 526 644 503 295 43 0 1
Industrial .............................. 296 297 293 281 284 301 301 305 302 307 306 308
Additional Firm .................... 125 121 119 121 117 114 122 122 118 118 127 128
Loss ..................................... 173 153 139 135 156 189 225 206 164 131 143 180
System Load ................... 1,936 1,726 1,578 1,538 1,747 2,085 2,461 2,265 1,834 1,508 1,635 2,007
Light Load ........................... 1,788 1,593 1,450 1,393 1,588 1,866 2,233 2,009 1,648 1,360 1,509 1,854
Heavy Load ......................... 2,052 1,826 1,670 1,654 1,872 2,245 2,657 2,449 1,997 1,615 1,737 2,139
Total Load ........................ 1,936 1,726 1,578 1,538 1,747 2,085 2,461 2,265 1,834 1,508 1,635 2,007
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,536 2,402 2,088 2,009 2,993 3,400 3,609 3,199 2,944 2,107 2,279 2,691
Total Peak Load .............. 2,536 2,402 2,088 2,009 2,993 3,400 3,609 3,199 2,944 2,107 2,279 2,691
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 15
Monthly Summary1 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)–50th Percentile
Residential .......................... 839 696 595 517 474 508 646 619 498 485 616 868
Commercial ......................... 516 466 440 422 429 461 539 526 470 434 455 538
Irrigation .............................. 2 2 2 72 300 527 646 504 296 43 0 1
Industrial .............................. 301 303 298 286 288 306 306 310 307 312 311 313
Additional Firm .................... 126 122 120 122 117 115 123 123 119 119 128 129
Loss ..................................... 175 154 140 136 157 191 228 208 166 133 145 182
System Load ................... 1,958 1,742 1,595 1,555 1,765 2,107 2,488 2,291 1,856 1,526 1,655 2,032
Light Load ........................... 1,808 1,608 1,466 1,409 1,605 1,886 2,258 2,032 1,667 1,376 1,527 1,877
Heavy Load ......................... 2,076 1,843 1,697 1,662 1,892 2,284 2,670 2,477 2,021 1,634 1,758 2,165
Total Load ........................ 1,958 1,742 1,595 1,555 1,765 2,107 2,488 2,291 1,856 1,526 1,655 2,032
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,560 2,418 2,107 2,028 3,036 3,439 3,664 3,239 2,983 2,126 2,301 2,716
Total Peak Load .............. 2,560 2,418 2,107 2,028 3,036 3,439 3,664 3,239 2,983 2,126 2,301 2,716

Monthly Summary1 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)–50th Percentile
Residential .......................... 846 699 600 521 478 515 656 628 504 490 622 878
Commercial ......................... 521 470 444 427 434 466 545 532 476 439 459 544
Irrigation .............................. 2 2 2 72 301 528 648 506 297 43 0 1
Industrial .............................. 306 297 303 290 293 312 312 315 313 317 316 318
Additional Firm .................... 132 124 126 127 122 119 127 128 123 124 134 136
Loss ..................................... 177 155 142 138 159 193 230 210 167 135 147 184
System Load ................... 1,984 1,746 1,616 1,576 1,787 2,133 2,517 2,319 1,880 1,547 1,678 2,061
Light Load ........................... 1,832 1,612 1,485 1,428 1,625 1,909 2,284 2,058 1,689 1,395 1,548 1,904
Heavy Load ......................... 2,103 1,846 1,719 1,685 1,927 2,297 2,701 2,525 2,033 1,657 1,792 2,185
Total Load ........................ 1,984 1,746 1,616 1,576 1,787 2,133 2,517 2,319 1,880 1,547 1,678 2,061
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,588 2,436 2,129 2,048 3,084 3,481 3,722 3,281 3,024 2,148 2,326 2,745
Total Peak Load .............. 2,588 2,436 2,129 2,048 3,084 3,481 3,722 3,281 3,024 2,148 2,326 2,745

Monthly Summary1 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)–50th Percentile
Residential .......................... 852 702 603 525 483 521 664 637 510 494 627 887
Commercial ......................... 525 473 448 431 438 471 551 538 481 444 464 550
Irrigation .............................. 2 2 2 72 301 529 649 507 297 43 0 1
Industrial .............................. 311 313 308 295 298 317 317 320 318 322 321 323
Additional Firm .................... 143 138 135 136 130 127 135 135 130 131 144 148
Loss ..................................... 179 157 143 140 161 195 232 213 169 136 149 187
System Load ................... 2,012 1,785 1,639 1,600 1,811 2,160 2,548 2,349 1,906 1,570 1,705 2,095
Light Load ........................... 1,858 1,647 1,506 1,449 1,647 1,934 2,312 2,084 1,712 1,416 1,573 1,936
Heavy Load ......................... 2,145 1,888 1,735 1,710 1,953 2,326 2,734 2,558 2,061 1,692 1,811 2,221
Total Load ........................ 2,012 1,785 1,639 1,600 1,811 2,160 2,548 2,349 1,906 1,570 1,705 2,095
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,614 2,462 2,148 2,064 3,135 3,523 3,782 3,324 3,067 2,173 2,350 2,776
Total Peak Load .............. 2,614 2,462 2,148 2,064 3,135 3,523 3,782 3,324 3,067 2,173 2,350 2,776
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 2013 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 2013 Integrated Resource Plan—Appendix C
Monthly Summary1 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)–50th Percentile
Residential .......................... 859 706 607 530 488 528 674 646 516 498 633 898
Commercial ......................... 530 477 452 435 443 477 557 544 487 449 468 556
Irrigation .............................. 2 2 2 72 301 528 648 506 297 43 0 1
Industrial .............................. 316 318 313 300 303 322 322 326 323 328 327 328
Additional Firm .................... 148 142 139 141 134 131 138 139 134 135 149 153
Loss ..................................... 181 158 145 141 162 196 234 215 171 138 150 189
System Load ................... 2,036 1,803 1,659 1,619 1,830 2,182 2,573 2,374 1,928 1,590 1,727 2,125
Light Load ........................... 1,881 1,664 1,524 1,466 1,664 1,953 2,335 2,106 1,732 1,434 1,594 1,963
Heavy Load ......................... 2,170 1,907 1,755 1,731 1,973 2,350 2,778 2,567 2,085 1,713 1,835 2,253
Total Load ........................ 2,036 1,803 1,659 1,619 1,830 2,182 2,573 2,374 1,928 1,590 1,727 2,125
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,636 2,480 2,164 2,077 3,180 3,559 3,835 3,361 3,104 2,194 2,370 2,803
Total Peak Load .............. 2,636 2,480 2,164 2,077 3,180 3,559 3,835 3,361 3,104 2,194 2,370 2,803

Monthly Summary1 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)–50th Percentile
Residential .......................... 868 711 613 536 494 536 685 656 523 504 640 908
Commercial ......................... 536 481 457 440 448 483 564 550 494 454 473 562
Irrigation .............................. 2 2 2 72 300 528 648 506 297 43 0 1
Industrial .............................. 321 323 318 305 308 327 327 331 328 333 332 333
Additional Firm .................... 148 143 140 141 135 132 139 139 134 136 150 153
Loss ..................................... 183 160 146 143 164 198 237 217 173 139 152 191
System Load ................... 2,058 1,819 1,676 1,636 1,848 2,204 2,599 2,399 1,949 1,608 1,747 2,149
Light Load ........................... 1,901 1,679 1,540 1,482 1,680 1,972 2,358 2,128 1,751 1,450 1,612 1,985
Heavy Load ......................... 2,194 1,924 1,774 1,760 1,981 2,373 2,806 2,594 2,108 1,733 1,855 2,290
Total Load ........................ 2,058 1,819 1,676 1,636 1,848 2,204 2,599 2,399 1,949 1,608 1,747 2,149
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,659 2,495 2,182 2,094 3,223 3,596 3,889 3,399 3,142 2,213 2,391 2,826
Total Peak Load .............. 2,659 2,495 2,182 2,094 3,223 3,596 3,889 3,399 3,142 2,213 2,391 2,826

Monthly Summary1 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)–50th Percentile
Residential .......................... 875 714 617 540 499 542 694 665 529 508 645 917
Commercial ......................... 540 485 461 444 452 487 569 556 499 459 477 567
Irrigation .............................. 2 2 2 72 301 529 649 507 297 43 0 1
Industrial .............................. 326 317 323 310 312 332 332 336 333 338 337 338
Additional Firm .................... 148 138 140 141 134 131 139 139 134 135 149 153
Loss ..................................... 185 160 147 144 165 200 239 219 175 141 153 193
System Load ................... 2,075 1,814 1,689 1,650 1,863 2,223 2,622 2,421 1,968 1,623 1,762 2,169
Light Load ........................... 1,917 1,674 1,552 1,495 1,694 1,989 2,379 2,148 1,768 1,464 1,626 2,004
Heavy Load ......................... 2,201 1,917 1,797 1,764 1,997 2,409 2,813 2,618 2,143 1,738 1,872 2,311
Total Load ........................ 2,075 1,814 1,689 1,650 1,863 2,223 2,622 2,421 1,968 1,623 1,762 2,169
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,668 2,502 2,186 2,096 3,263 3,630 3,939 3,433 3,176 2,228 2,399 2,840
Total Peak Load .............. 2,668 2,502 2,186 2,096 3,263 3,630 3,939 3,433 3,176 2,228 2,399 2,840
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 17

Monthly Summary1 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)–50th Percentile
Residential .......................... 881 716 620 544 503 548 703 673 534 511 650 927
Commercial ......................... 544 487 464 447 455 492 574 561 504 463 481 573
Irrigation .............................. 2 2 2 72 300 528 647 505 297 43 0 1
Industrial .............................. 330 333 327 314 317 337 337 341 338 343 342 343
Additional Firm .................... 148 143 140 141 135 132 139 140 135 136 150 153
Loss ..................................... 186 162 148 145 166 201 240 221 176 142 155 195
System Load ................... 2,091 1,841 1,701 1,663 1,876 2,238 2,640 2,439 1,984 1,637 1,777 2,193
Light Load ........................... 1,931 1,699 1,563 1,506 1,706 2,003 2,396 2,164 1,782 1,476 1,639 2,026
Heavy Load ......................... 2,217 1,948 1,810 1,777 2,011 2,426 2,833 2,656 2,145 1,753 1,898 2,324
Total Load ........................ 2,091 1,841 1,701 1,663 1,876 2,238 2,640 2,439 1,984 1,637 1,777 2,193
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,670 2,511 2,184 2,088 3,302 3,657 3,985 3,461 3,205 2,242 2,402 2,855
Total Peak Load .............. 2,670 2,511 2,184 2,088 3,302 3,657 3,985 3,461 3,205 2,242 2,402 2,855

Monthly Summary1 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)–50th Percentile
Residential .......................... 890 721 625 550 509 557 715 684 542 517 657 940
Commercial ......................... 549 492 469 452 461 498 581 568 511 468 486 579
Irrigation .............................. 2 2 2 72 298 525 643 502 295 43 0 1
Industrial .............................. 335 338 332 319 322 342 342 346 343 348 347 348
Additional Firm .................... 147 142 139 140 134 131 139 139 134 135 149 152
Loss ..................................... 188 163 150 146 168 203 242 222 178 143 156 198
System Load ................... 2,112 1,857 1,718 1,679 1,892 2,256 2,662 2,461 2,003 1,654 1,796 2,219
Light Load ........................... 1,951 1,714 1,578 1,521 1,720 2,019 2,415 2,183 1,799 1,492 1,657 2,050
Heavy Load ......................... 2,240 1,964 1,827 1,795 2,040 2,429 2,856 2,680 2,166 1,772 1,918 2,352
Total Load ........................ 2,112 1,857 1,718 1,679 1,892 2,256 2,662 2,461 2,003 1,654 1,796 2,219
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,691 2,525 2,199 2,102 3,343 3,688 4,034 3,494 3,240 2,259 2,421 2,879
Total Peak Load .............. 2,691 2,525 2,199 2,102 3,343 3,688 4,034 3,494 3,240 2,259 2,421 2,879

Monthly Summary1 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)–50th Percentile
Residential .......................... 900 726 631 556 516 565 727 695 549 523 665 951
Commercial ......................... 555 496 475 457 466 505 588 575 518 474 492 586
Irrigation .............................. 2 2 2 72 299 525 644 503 295 43 0 1
Industrial .............................. 340 343 337 323 327 347 347 351 348 353 352 353
Additional Firm .................... 147 142 139 140 134 131 139 139 134 135 149 152
Loss ..................................... 190 165 151 148 169 205 245 225 180 145 158 200
System Load ................... 2,135 1,873 1,735 1,697 1,911 2,279 2,690 2,488 2,025 1,673 1,816 2,243
Light Load ........................... 1,972 1,728 1,594 1,537 1,737 2,039 2,440 2,207 1,819 1,509 1,675 2,072
Heavy Load ......................... 2,275 1,981 1,837 1,814 2,060 2,454 2,886 2,709 2,190 1,803 1,928 2,378
Total Load ........................ 2,135 1,873 1,735 1,697 1,911 2,279 2,690 2,488 2,025 1,673 1,816 2,243
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,714 2,539 2,217 2,120 3,386 3,729 4,090 3,535 3,281 2,278 2,442 2,902
Total Peak Load .............. 2,714 2,539 2,217 2,120 3,386 3,729 4,090 3,535 3,281 2,278 2,442 2,902
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 2013 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 2013 Integrated Resource Plan—Appendix C
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)–50th Percentile
Residential .......................... 907 729 635 560 521 572 736 704 556 527 670 962
Commercial ......................... 560 500 479 462 471 510 594 581 525 479 496 593
Irrigation .............................. 2 2 2 72 299 527 645 504 296 43 0 1
Industrial .............................. 345 335 342 328 331 352 352 356 353 358 357 358
Additional Firm .................... 146 136 138 139 133 130 138 138 133 134 147 150
Loss ..................................... 192 164 153 149 171 207 247 227 182 146 160 202
System Load ................... 2,152 1,866 1,748 1,710 1,926 2,298 2,713 2,510 2,044 1,688 1,831 2,266
Light Load ........................... 1,987 1,722 1,606 1,549 1,751 2,057 2,462 2,227 1,836 1,522 1,689 2,094
Heavy Load ......................... 2,293 1,973 1,850 1,839 2,064 2,474 2,929 2,715 2,210 1,819 1,945 2,415
Total Load ........................ 2,152 1,866 1,748 1,710 1,926 2,298 2,713 2,510 2,044 1,688 1,831 2,266
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,721 2,548 2,220 2,120 3,427 3,763 4,141 3,570 3,316 2,293 2,449 2,918
Total Peak Load .............. 2,721 2,548 2,220 2,120 3,427 3,763 4,141 3,570 3,316 2,293 2,449 2,918

Monthly Summary1 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 .......................... 916 734 640 566 527 580 748 715 563 533 678 974
Commercial ......................... 567 505 484 467 476 517 602 589 532 486 502 600
Irrigation .............................. 2 2 2 72 298 525 643 502 295 43 0 1
Industrial .............................. 350 352 347 333 336 357 357 361 358 363 362 363
Additional Firm .................... 145 140 137 139 133 130 138 138 133 134 146 149
Loss ..................................... 194 167 154 151 172 209 249 229 184 148 161 205
System Load ................... 2,173 1,899 1,764 1,727 1,942 2,318 2,737 2,534 2,065 1,706 1,850 2,293
Light Load ........................... 2,007 1,753 1,621 1,564 1,766 2,074 2,483 2,248 1,855 1,538 1,706 2,119
Heavy Load ......................... 2,304 2,009 1,868 1,857 2,082 2,496 2,955 2,741 2,248 1,827 1,965 2,443
Total Load ........................ 2,173 1,899 1,764 1,727 1,942 2,318 2,737 2,534 2,065 1,706 1,850 2,293
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,740 2,560 2,234 2,132 3,468 3,798 4,192 3,606 3,353 2,311 2,466 2,942
Total Peak Load .............. 2,740 2,560 2,234 2,132 3,468 3,798 4,192 3,606 3,353 2,311 2,466 2,942

Monthly Summary1 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)–50th Percentile
Residential .......................... 926 739 646 572 534 589 761 727 571 539 686 986
Commercial ......................... 573 510 490 473 483 525 610 597 540 492 508 608
Irrigation .............................. 2 2 2 72 299 525 644 502 295 43 0 1
Industrial .............................. 355 357 352 337 341 362 362 366 363 368 367 368
Additional Firm .................... 152 147 144 145 138 136 143 143 138 139 154 158
Loss ..................................... 196 169 156 153 174 211 252 232 186 150 164 207
System Load ................... 2,205 1,924 1,790 1,752 1,968 2,347 2,771 2,568 2,093 1,731 1,879 2,329
Light Load ........................... 2,036 1,775 1,645 1,587 1,789 2,101 2,515 2,278 1,881 1,562 1,733 2,152
Heavy Load ......................... 2,338 2,035 1,904 1,873 2,109 2,545 2,974 2,777 2,280 1,854 1,996 2,482
Total Load ........................ 2,205 1,924 1,790 1,752 1,968 2,347 2,771 2,568 2,093 1,731 1,879 2,329
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,776 2,586 2,262 2,159 3,519 3,847 4,256 3,656 3,402 2,338 2,498 2,979
Total Peak Load .............. 2,776 2,586 2,262 2,159 3,519 3,847 4,256 3,656 3,402 2,338 2,498 2,979
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 19
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)–50th Percentile
Residential .......................... 934 743 651 578 539 597 772 737 578 544 692 997
Commercial ......................... 580 516 496 479 489 532 618 605 548 499 514 616
Irrigation .............................. 2 2 2 72 299 526 645 504 296 43 0 1
Industrial .............................. 360 362 356 342 345 367 367 371 368 373 372 374
Additional Firm .................... 151 146 143 144 138 135 143 143 138 139 153 156
Loss ..................................... 198 170 157 154 176 213 255 235 188 152 165 210
System Load ................... 2,226 1,938 1,806 1,769 1,987 2,370 2,799 2,595 2,116 1,749 1,897 2,355
Light Load ........................... 2,055 1,789 1,659 1,602 1,806 2,121 2,540 2,302 1,901 1,578 1,750 2,175
Heavy Load ......................... 2,349 2,050 1,921 1,891 2,117 2,570 2,987 2,825 2,273 1,873 2,015 2,484
Total Load ........................ 2,226 1,938 1,806 1,769 1,987 2,370 2,799 2,595 2,116 1,749 1,897 2,355
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,791 2,597 2,272 2,167 3,562 3,888 4,312 3,697 3,443 2,356 2,513 2,999
Total Peak Load .............. 2,791 2,597 2,272 2,167 3,562 3,888 4,312 3,697 3,443 2,356 2,513 2,999

Monthly Summary1 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 .......................... 942 746 655 583 545 605 782 747 585 549 698 1,008
Commercial ......................... 587 521 502 485 495 539 627 613 557 506 521 625
Irrigation .............................. 2 2 2 72 299 526 644 503 295 43 0 1
Industrial .............................. 365 355 361 347 350 372 372 376 373 379 377 379
Additional Firm .................... 151 140 142 144 137 135 142 142 137 138 152 156
Loss ..................................... 200 170 159 156 177 215 257 237 190 153 167 212
System Load ................... 2,246 1,933 1,822 1,786 2,004 2,391 2,825 2,619 2,137 1,767 1,916 2,380
Light Load ........................... 2,074 1,784 1,674 1,617 1,822 2,140 2,563 2,324 1,920 1,594 1,768 2,199
Heavy Load ......................... 2,370 2,055 1,928 1,909 2,147 2,575 3,014 2,852 2,296 1,904 2,025 2,511
Total Load ........................ 2,246 1,933 1,822 1,786 2,004 2,391 2,825 2,619 2,137 1,767 1,916 2,380
Peak Load (MW)–90th Percentile
System Peak (1 hour) ..... 2,807 2,596 2,282 2,174 3,603 3,925 4,365 3,735 3,482 2,374 2,527 3,020
Total Peak Load .............. 2,807 2,596 2,282 2,174 3,603 3,925 4,365 3,735 3,482 2,374 2,527 3,020
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 2013 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 20 2013 Integrated Resource Plan—Appendix C
Annual Summary
2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Billed Sales (MWh)–50th Percentile
Residential ......................... 5,024,661 5,054,545 5,063,083 5,130,952 5,221,061 5,299,496 5,371,170 5,426,100 5,476,110 5,532,311
Commercial ........................ 3,900,064 3,960,646 3,996,617 4,043,282 4,082,719 4,117,425 4,158,116 4,202,778 4,244,120 4,288,491
Irrigation ............................. 1,751,463 1,762,474 1,768,998 1,750,913 1,749,671 1,756,095 1,760,483 1,765,522 1,768,531 1,765,357
Industrial ............................. 2,334,380 2,402,175 2,466,748 2,523,489 2,568,734 2,609,536 2,653,663 2,698,998 2,743,911 2,788,219
Additional Firm ................... 1,009,771 1,025,200 1,052,800 1,053,500 1,062,300 1,059,600 1,067,700 1,115,100 1,193,100 1,228,700
System Sales.................. 14,020,339 14,205,040 14,348,247 14,502,137 14,684,485 14,842,152 15,011,132 15,208,498 15,425,772 15,603,078
Total Sales ...................... 14,020,339 14,205,040 14,348,247 14,502,137 14,684,485 14,842,152 15,011,132 15,208,498 15,425,772 15,603,078
Generation Month Sales (MWh)–50th Percentile
Residential ......................... 5,027,296 5,055,690 5,068,397 5,154,035 5,227,150 5,305,125 5,375,632 5,447,007 5,480,685 5,537,710
Commercial ........................ 3,903,440 3,962,715 3,999,260 4,056,500 4,084,729 4,119,758 4,160,664 4,216,430 4,246,659 4,291,303
Irrigation ............................. 1,751,467 1,762,477 1,768,991 1,750,951 1,749,674 1,756,097 1,760,485 1,765,562 1,768,530 1,765,357
Industrial ............................. 2,340,228 2,407,744 2,471,642 2,527,392 2,572,253 2,613,342 2,657,573 2,702,871 2,747,733 2,792,033
Additional Firm ................... 1,009,771 1,025,200 1,052,800 1,053,500 1,062,300 1,059,600 1,067,700 1,115,100 1,193,100 1,228,700
System Sales.................. 14,032,203 14,213,826 14,361,089 14,542,378 14,696,106 14,853,922 15,022,054 15,246,971 15,436,707 15,615,103
Total Sales ...................... 14,032,203 14,213,826 14,361,089 14,542,378 14,696,106 14,853,922 15,022,054 15,246,971 15,436,707 15,615,103
Loss .................................... 1,380,235 1,396,630 1,408,407 1,426,063 1,440,637 1,456,526 1,472,745 1,492,086 1,505,449 1,520,629
Required Generation ..... 15,412,437 15,610,455 15,769,496 15,968,441 16,136,743 16,310,448 16,494,799 16,739,057 16,942,156 17,135,732
Average Load (aMW)–50th Percentile
Residential ......................... 574 577 579 587 597 606 614 620 626 632
Commercial ........................ 446 452 457 462 466 470 475 480 485 490
Irrigation ............................. 200 201 202 199 200 200 201 201 202 202
Industrial ............................. 267 275 282 288 294 298 303 308 314 319
Additional Firm ................... 115 117 120 120 121 121 122 127 136 140
Loss .................................... 158 159 161 162 164 166 168 170 172 174
System Load .................. 1,759 1,782 1,800 1,818 1,842 1,862 1,883 1,906 1,934 1,956
Light Load .......................... 1,599 1,620 1,636 1,653 1,674 1,693 1,712 1,732 1,758 1,778
Heavy Load ........................ 1,885 1,909 1,928 1,947 1,974 1,995 2,017 2,041 2,072 2,096
Total Load ....................... 1,759 1,782 1,800 1,818 1,842 1,862 1,883 1,906 1,934 1,956
Peak Load (MW)–90th Percentile
System Peak (1 Hour).... 3,344 3,403 3,456 3,500 3,555 3,609 3,664 3,722 3,782 3,835
Total Peak Load ............. 3,344 3,403 3,456 3,500 3,555 3,609 3,664 3,722 3,782 3,835

Idaho Power Company Sales and Load Forecast Data
2013 Integrated Resource Plan—Appendix C Page 21
2023 2024 2024 2026 2027 2028 2029 2030 2031 2032
Billed Sales (MWh)–50th Percentile
Residential ......................... 5,599,951 5,652,900 5,698,298 5,769,278 5,841,976 5,896,722 5,965,645 6,041,626 6,104,767 6,163,934
Commercial ........................ 4,337,889 4,377,042 4,412,765 4,464,888 4,517,788 4,562,924 4,618,921 4,680,777 4,740,317 4,802,348
Irrigation ............................. 1,764,576 1,768,216 1,763,156 1,752,206 1,754,887 1,758,862 1,752,877 1,753,702 1,757,850 1,755,683
Industrial ............................. 2,832,435 2,875,947 2,917,139 2,961,183 3,005,317 3,047,482 3,090,882 3,134,512 3,177,840 3,222,016
Additional Firm ................... 1,234,000 1,231,300 1,234,000 1,228,400 1,228,300 1,217,500 1,212,000 1,268,000 1,262,200 1,257,000
System Sales.................. 15,768,851 15,905,405 16,025,359 16,175,955 16,348,269 16,483,491 16,640,325 16,878,617 17,042,974 17,200,980
Total Sales ...................... 15,768,851 15,905,405 16,025,359 16,175,955 16,348,269 16,483,491 16,640,325 16,878,617 17,042,974 17,200,980
Generation Month Sales (MWh)–50th Percentile
Residential ......................... 5,604,321 5,673,871 5,703,975 5,775,094 5,846,523 5,919,794 5,971,741 6,046,816 6,109,685 6,186,758
Commercial ........................ 4,340,155 4,390,757 4,415,734 4,467,902 4,520,389 4,578,115 4,622,430 4,684,166 4,743,845 4,818,548
Irrigation ............................. 1,764,577 1,768,253 1,763,152 1,752,207 1,754,889 1,758,898 1,752,877 1,753,704 1,757,849 1,755,721
Industrial ............................. 2,836,188 2,879,500 2,920,938 2,964,990 3,008,954 3,051,226 3,094,645 3,138,249 3,181,650 3,225,818
Additional Firm ................... 1,234,000 1,231,300 1,234,000 1,228,400 1,228,300 1,217,500 1,212,000 1,268,000 1,262,200 1,257,000
System Sales.................. 15,779,241 15,943,680 16,037,799 16,188,593 16,359,055 16,525,533 16,653,693 16,890,934 17,055,229 17,243,844
Total Sales ...................... 15,779,241 15,943,680 16,037,799 16,188,593 16,359,055 16,525,533 16,653,693 16,890,934 17,055,229 17,243,844
Loss .................................... 1,536,622 1,553,151 1,561,805 1,577,035 1,594,124 1,611,513 1,624,411 1,644,521 1,661,381 1,680,699
Required Generation ..... 17,315,863 17,496,832 17,599,604 17,765,627 17,953,179 18,137,046 18,278,105 18,535,456 18,716,610 18,924,543
Average Load (aMW)–50th Percentile
Residential ......................... 640 646 651 659 667 674 682 690 697 704
Commercial ........................ 495 500 504 510 516 521 528 535 542 549
Irrigation ............................. 201 201 201 200 200 200 200 200 201 200
Industrial ............................. 324 328 333 338 343 347 353 358 363 367
Additional Firm ................... 141 140 141 140 140 139 138 145 144 143
Loss .................................... 175 177 178 180 182 183 185 188 190 191
System Load .................. 1,977 1,992 2,009 2,028 2,049 2,065 2,087 2,116 2,137 2,154
Light Load .......................... 1,797 1,811 1,826 1,844 1,863 1,877 1,897 1,923 1,942 1,959
Heavy Load ........................ 2,119 2,134 2,153 2,172 2,196 2,213 2,236 2,267 2,283 2,301
Total Load ....................... 1,977 1,992 2,009 2,028 2,049 2,065 2,087 2,116 2,137 2,154
Peak Load (MW)–90th Percentile
System Peak (1 Hour).... 3,889 3,939 3,985 4,034 4,090 4,141 4,192 4,256 4,312 4,365
Total Peak Load ............. 3,889 3,939 3,985 4,034 4,090 4,141 4,192 4,256 4,312 4,365

Sales and Load Forecast Data Idaho Power Company
Page 22 2013 Integrated Resource Plan—Appendix C
70th Percentile Load Forecast
Monthly Summary1 1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013
Average Load (aMW)–70th Percentile
Residential .......................... 816 698 581 494 457 491 612 579 471 468 592 820
Commercial ......................... 496 453 419 402 410 436 510 495 439 409 432 510
Irrigation .............................. 2 2 2 91 352 570 663 517 312 47 0 1
Industrial .............................. 264 266 262 251 254 270 269 273 270 274 273 278
Additional Firm .................... 118 116 113 115 110 112 116 116 112 112 120 122
Loss ..................................... 168 150 133 131 156 188 219 199 158 126 137 171
System Load ................... 1,864 1,684 1,511 1,484 1,740 2,067 2,390 2,178 1,762 1,437 1,555 1,902
Light Load ........................... 1,722 1,554 1,388 1,344 1,582 1,850 2,168 1,933 1,583 1,296 1,435 1,757
Heavy Load ......................... 1,977 1,782 1,607 1,586 1,865 2,241 2,564 2,356 1,919 1,539 1,652 2,027
Total Load ........................ 1,864 1,684 1,511 1,484 1,740 2,067 2,390 2,178 1,762 1,437 1,555 1,902
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,505 2,384 2,092 1,971 2,805 3,264 3,382 3,027 2,778 2,026 2,267 2,683
Total Peak Load .............. 2,505 2,384 2,092 1,971 2,805 3,264 3,382 3,027 2,778 2,026 2,267 2,683

Monthly Summary1 1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014
Average Load (aMW)–70th Percentile
Residential .......................... 820 699 583 496 460 496 618 585 474 470 595 823
Commercial ......................... 503 459 425 408 416 444 518 503 447 416 438 517
Irrigation .............................. 2 2 2 91 354 574 667 520 314 48 0 1
Industrial .............................. 272 274 269 259 261 277 277 281 278 282 281 286
Additional Firm .................... 121 117 115 117 113 110 118 118 114 114 122 124
Loss ..................................... 170 152 135 133 158 190 222 201 160 127 139 172
System Load ................... 1,887 1,702 1,530 1,503 1,763 2,090 2,421 2,208 1,788 1,457 1,576 1,923
Light Load ........................... 1,743 1,570 1,406 1,362 1,603 1,871 2,197 1,959 1,606 1,314 1,454 1,777
Heavy Load ......................... 2,001 1,800 1,627 1,607 1,889 2,266 2,598 2,404 1,933 1,561 1,683 2,039
Total Load ........................ 1,887 1,702 1,530 1,503 1,763 2,090 2,421 2,208 1,788 1,457 1,576 1,923
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,534 2,403 2,115 1,996 2,852 3,310 3,442 3,071 2,822 2,047 2,289 2,704
Total Peak Load .............. 2,534 2,403 2,115 1,996 2,852 3,310 3,442 3,071 2,822 2,047 2,289 2,704

Monthly Summary1 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)–70th Percentile
Residential .......................... 820 696 582 496 462 499 622 588 476 470 596 831
Commercial ......................... 507 462 428 412 420 448 524 508 452 420 442 522
Irrigation .............................. 2 2 2 91 355 576 669 522 315 48 0 1
Industrial .............................. 279 281 277 265 268 285 285 288 286 290 289 293
Additional Firm .................... 124 121 119 120 116 113 121 121 117 117 126 128
Loss ..................................... 171 152 136 134 160 192 224 203 162 129 140 175
System Load ................... 1,903 1,714 1,544 1,519 1,780 2,112 2,445 2,231 1,807 1,473 1,593 1,949
Light Load ........................... 1,758 1,582 1,418 1,376 1,619 1,890 2,219 1,979 1,624 1,329 1,470 1,800
Heavy Load ......................... 2,018 1,813 1,642 1,623 1,920 2,274 2,624 2,429 1,954 1,578 1,701 2,066
Total Load ........................ 1,903 1,714 1,544 1,519 1,780 2,112 2,445 2,231 1,807 1,473 1,593 1,949
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,530 2,413 2,108 1,980 2,898 3,345 3,495 3,106 2,856 2,065 2,289 2,718
Total Peak Load .............. 2,530 2,413 2,108 1,980 2,898 3,345 3,495 3,106 2,856 2,065 2,289 2,718
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 23
Monthly Summary1 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)–70th Percentile
Residential .......................... 829 702 588 502 468 507 634 599 483 476 603 845
Commercial ......................... 512 466 433 416 425 454 530 514 458 425 447 528
Irrigation .............................. 2 2 2 91 352 570 663 517 312 47 0 1
Industrial .............................. 286 278 283 272 274 291 291 295 292 296 296 298
Additional Firm .................... 124 117 119 120 116 113 121 121 117 117 126 128
Loss ..................................... 173 153 137 135 161 193 226 205 163 130 142 177
System Load ................... 1,927 1,717 1,562 1,536 1,797 2,129 2,465 2,251 1,826 1,492 1,614 1,976
Light Load ........................... 1,779 1,585 1,436 1,391 1,633 1,905 2,236 1,997 1,640 1,346 1,489 1,826
Heavy Load ......................... 2,053 1,815 1,654 1,642 1,937 2,292 2,661 2,434 1,974 1,608 1,714 2,095
Total Load ........................ 1,927 1,717 1,562 1,536 1,797 2,129 2,465 2,251 1,826 1,492 1,614 1,976
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,546 2,426 2,118 1,986 2,937 3,371 3,541 3,134 2,888 2,083 2,303 2,738
Total Peak Load .............. 2,546 2,426 2,118 1,986 2,937 3,371 3,541 3,134 2,888 2,083 2,303 2,738

Monthly Summary1 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)–70th Percentile
Residential .......................... 842 711 597 511 477 518 648 612 492 484 613 859
Commercial ......................... 517 470 437 420 429 459 535 520 463 430 451 533
Irrigation .............................. 2 2 2 91 352 570 662 517 312 47 0 1
Industrial .............................. 291 293 288 276 279 297 296 300 298 302 301 303
Additional Firm .................... 125 122 120 121 117 114 122 122 118 118 127 129
Loss ..................................... 175 156 139 137 163 195 228 207 165 132 144 180
System Load ................... 1,952 1,752 1,582 1,556 1,817 2,152 2,493 2,278 1,849 1,513 1,636 2,004
Light Load ........................... 1,803 1,617 1,454 1,409 1,652 1,926 2,262 2,021 1,661 1,364 1,509 1,851
Heavy Load ......................... 2,081 1,854 1,675 1,673 1,947 2,318 2,691 2,463 1,999 1,630 1,738 2,135
Total Load ........................ 1,952 1,752 1,582 1,556 1,817 2,152 2,493 2,278 1,849 1,513 1,636 2,004
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,574 2,445 2,139 2,007 2,982 3,410 3,596 3,174 2,929 2,103 2,328 2,765
Total Peak Load .............. 2,574 2,445 2,139 2,007 2,982 3,410 3,596 3,174 2,929 2,103 2,328 2,765

Monthly Summary1 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)–70th Percentile
Residential .......................... 853 718 604 518 484 527 661 624 501 490 621 872
Commercial ......................... 521 472 440 424 433 463 540 525 468 434 455 538
Irrigation .............................. 2 2 2 91 353 572 665 518 313 47 0 1
Industrial .............................. 296 297 293 281 284 301 301 305 302 307 306 308
Additional Firm .................... 125 121 119 121 117 114 122 122 118 118 127 128
Loss ..................................... 177 157 141 138 164 197 231 209 167 134 145 182
System Load ................... 1,974 1,768 1,599 1,572 1,835 2,175 2,520 2,303 1,869 1,529 1,654 2,029
Light Load ........................... 1,823 1,631 1,469 1,424 1,668 1,946 2,286 2,043 1,679 1,379 1,526 1,874
Heavy Load ......................... 2,093 1,870 1,692 1,691 1,966 2,342 2,720 2,491 2,036 1,638 1,757 2,162
Total Load ........................ 1,974 1,768 1,599 1,572 1,835 2,175 2,520 2,303 1,869 1,529 1,654 2,029
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,595 2,459 2,156 2,023 3,025 3,448 3,651 3,212 2,966 2,120 2,347 2,789
Total Peak Load .............. 2,595 2,459 2,156 2,023 3,025 3,448 3,651 3,212 2,966 2,120 2,347 2,789
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 2013 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 2013 Integrated Resource Plan—Appendix C
Monthly Summary1 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)–70th Percentile
Residential .......................... 863 724 610 524 491 536 673 635 508 496 629 882
Commercial ......................... 525 476 444 428 437 469 546 530 474 438 459 544
Irrigation .............................. 2 2 2 91 354 573 666 520 314 47 0 1
Industrial .............................. 301 303 298 286 288 306 306 310 307 312 311 313
Additional Firm .................... 126 122 120 122 117 115 123 123 119 119 128 129
Loss ..................................... 179 158 142 140 166 199 233 212 169 135 147 184
System Load ................... 1,996 1,785 1,616 1,590 1,854 2,198 2,547 2,330 1,891 1,548 1,674 2,054
Light Load ........................... 1,844 1,647 1,485 1,440 1,686 1,967 2,311 2,067 1,699 1,396 1,544 1,897
Heavy Load ......................... 2,117 1,888 1,719 1,699 1,987 2,383 2,734 2,519 2,060 1,657 1,778 2,188
Total Load ........................ 1,996 1,785 1,616 1,590 1,854 2,198 2,547 2,330 1,891 1,548 1,674 2,054
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,620 2,474 2,175 2,042 3,068 3,487 3,707 3,251 3,005 2,139 2,368 2,814
Total Peak Load .............. 2,620 2,474 2,175 2,042 3,068 3,487 3,707 3,251 3,005 2,139 2,368 2,814

Monthly Summary1 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)–70th Percentile
Residential .......................... 870 727 614 529 496 544 683 644 514 501 635 891
Commercial ......................... 531 480 449 432 442 474 552 537 480 443 464 550
Irrigation .............................. 2 2 2 91 355 575 668 521 315 48 0 1
Industrial .............................. 306 297 303 290 293 312 312 315 313 317 316 318
Additional Firm .................... 132 124 126 127 122 119 127 128 123 124 134 136
Loss ..................................... 181 159 144 141 168 202 236 214 171 137 149 186
System Load ................... 2,022 1,789 1,637 1,611 1,877 2,225 2,578 2,359 1,916 1,569 1,698 2,083
Light Load ........................... 1,868 1,651 1,504 1,459 1,706 1,991 2,339 2,093 1,721 1,415 1,566 1,924
Heavy Load ......................... 2,144 1,891 1,741 1,722 2,023 2,396 2,766 2,568 2,072 1,680 1,813 2,208
Total Load ........................ 2,022 1,789 1,637 1,611 1,877 2,225 2,578 2,359 1,916 1,569 1,698 2,083
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,648 2,493 2,197 2,063 3,117 3,529 3,766 3,293 3,046 2,161 2,394 2,843
Total Peak Load .............. 2,648 2,493 2,197 2,063 3,117 3,529 3,766 3,293 3,046 2,161 2,394 2,843

Monthly Summary1 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)–70th Percentile
Residential .......................... 877 730 617 533 501 550 692 653 520 505 640 901
Commercial ......................... 535 484 453 436 446 479 558 542 485 448 468 555
Irrigation .............................. 2 2 2 91 355 575 669 522 315 48 0 1
Industrial .............................. 311 313 308 295 298 317 317 320 318 322 321 323
Additional Firm .................... 143 138 135 136 130 127 135 135 130 131 144 148
Loss ..................................... 183 161 145 143 170 204 238 216 173 138 150 189
System Load ................... 2,051 1,828 1,660 1,635 1,901 2,253 2,609 2,389 1,942 1,592 1,725 2,117
Light Load ........................... 1,894 1,687 1,526 1,481 1,728 2,017 2,368 2,120 1,744 1,436 1,591 1,956
Heavy Load ......................... 2,186 1,933 1,758 1,748 2,050 2,426 2,800 2,601 2,100 1,716 1,832 2,244
Total Load ........................ 2,051 1,828 1,660 1,635 1,901 2,253 2,609 2,389 1,942 1,592 1,725 2,117
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,674 2,519 2,216 2,079 3,168 3,572 3,827 3,337 3,088 2,186 2,418 2,874
Total Peak Load .............. 2,674 2,519 2,216 2,079 3,168 3,572 3,827 3,337 3,088 2,186 2,418 2,874
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 25
Monthly Summary1 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)–70th Percentile
Residential .......................... 884 734 622 537 507 558 702 662 526 509 646 912
Commercial ......................... 540 488 457 440 451 485 564 548 492 453 473 562
Irrigation .............................. 2 2 2 91 355 575 668 521 315 48 0 1
Industrial .............................. 316 318 313 300 303 322 322 326 323 328 327 328
Additional Firm .................... 148 142 139 141 134 131 138 139 134 135 149 153
Loss ..................................... 185 163 147 145 171 205 240 219 175 140 152 191
System Load ................... 2,075 1,846 1,680 1,654 1,921 2,276 2,635 2,414 1,964 1,612 1,747 2,147
Light Load ........................... 1,917 1,703 1,543 1,498 1,746 2,037 2,391 2,142 1,764 1,454 1,611 1,984
Heavy Load ......................... 2,212 1,953 1,778 1,768 2,071 2,451 2,845 2,611 2,123 1,737 1,855 2,276
Total Load ........................ 2,075 1,846 1,680 1,654 1,921 2,276 2,635 2,414 1,964 1,612 1,747 2,147
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,696 2,537 2,232 2,092 3,213 3,608 3,881 3,374 3,126 2,207 2,438 2,901
Total Peak Load .............. 2,696 2,537 2,232 2,092 3,213 3,608 3,881 3,374 3,126 2,207 2,438 2,901

Monthly Summary1 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)–70th Percentile
Residential .......................... 893 739 627 543 513 566 714 673 533 515 653 922
Commercial ......................... 546 492 462 445 456 491 571 555 498 458 478 568
Irrigation .............................. 2 2 2 91 355 574 668 521 315 48 0 1
Industrial .............................. 321 323 318 305 308 327 327 331 328 333 332 333
Additional Firm .................... 148 143 140 141 135 132 139 139 134 136 150 153
Loss ..................................... 187 164 148 146 173 207 243 221 177 141 154 193
System Load ................... 2,097 1,862 1,697 1,672 1,940 2,298 2,662 2,440 1,985 1,630 1,766 2,171
Light Load ........................... 1,937 1,719 1,559 1,514 1,763 2,057 2,415 2,165 1,783 1,470 1,630 2,006
Heavy Load ......................... 2,235 1,970 1,796 1,798 2,078 2,475 2,874 2,638 2,147 1,757 1,876 2,313
Total Load ........................ 2,097 1,862 1,697 1,672 1,940 2,298 2,662 2,440 1,985 1,630 1,766 2,171
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,719 2,551 2,249 2,109 3,257 3,645 3,935 3,412 3,164 2,225 2,458 2,924
Total Peak Load .............. 2,719 2,551 2,249 2,109 3,257 3,645 3,935 3,412 3,164 2,225 2,458 2,924

Monthly Summary1 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)–70th Percentile
Residential .......................... 900 742 631 548 519 574 724 682 539 519 658 931
Commercial ......................... 551 495 466 449 460 496 576 561 504 463 482 573
Irrigation .............................. 2 2 2 91 355 575 669 522 315 48 0 1
Industrial .............................. 326 317 323 310 312 332 332 336 333 338 337 338
Additional Firm .................... 148 138 140 141 134 131 139 139 134 135 149 153
Loss ..................................... 188 164 149 147 174 209 245 223 178 143 155 195
System Load ................... 2,115 1,857 1,710 1,686 1,955 2,318 2,685 2,462 2,004 1,645 1,782 2,191
Light Load ........................... 1,953 1,714 1,572 1,527 1,778 2,075 2,437 2,185 1,800 1,484 1,644 2,024
Heavy Load ......................... 2,242 1,963 1,820 1,802 2,095 2,513 2,882 2,663 2,182 1,762 1,893 2,334
Total Load ........................ 2,115 1,857 1,710 1,686 1,955 2,318 2,685 2,462 2,004 1,645 1,782 2,191
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,728 2,558 2,254 2,111 3,298 3,679 3,987 3,445 3,198 2,240 2,467 2,938
Total Peak Load .............. 2,728 2,558 2,254 2,111 3,298 3,679 3,987 3,445 3,198 2,240 2,467 2,938
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 2013 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 2013 Integrated Resource Plan—Appendix C
Monthly Summary1 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)–70th Percentile
Residential .......................... 905 744 634 551 523 580 733 690 545 522 663 941
Commercial ......................... 554 498 469 453 464 501 581 566 509 467 485 579
Irrigation .............................. 2 2 2 91 354 574 667 520 314 48 0 1
Industrial .............................. 330 333 327 314 317 337 337 341 338 343 342 343
Additional Firm .................... 148 143 140 141 135 132 139 140 135 136 150 153
Loss ..................................... 190 166 150 148 175 211 247 225 180 144 157 197
System Load ................... 2,130 1,885 1,723 1,699 1,969 2,334 2,705 2,481 2,020 1,659 1,796 2,215
Light Load ........................... 1,967 1,739 1,583 1,538 1,790 2,089 2,454 2,201 1,815 1,496 1,657 2,046
Heavy Load ......................... 2,259 1,994 1,833 1,816 2,110 2,530 2,902 2,702 2,184 1,777 1,918 2,348
Total Load ........................ 2,130 1,885 1,723 1,699 1,969 2,334 2,705 2,481 2,020 1,659 1,796 2,215
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,730 2,568 2,252 2,103 3,337 3,705 4,033 3,473 3,226 2,254 2,470 2,952
Total Peak Load .............. 2,730 2,568 2,252 2,103 3,337 3,705 4,033 3,473 3,226 2,254 2,470 2,952

Monthly Summary1 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)–70th Percentile
Residential .......................... 915 749 640 557 530 589 745 702 552 528 670 954
Commercial ......................... 560 503 474 458 470 507 589 573 516 473 491 586
Irrigation .............................. 2 2 2 91 353 571 663 517 312 47 0 1
Industrial .............................. 335 338 332 319 322 342 342 346 343 348 347 348
Additional Firm .................... 147 142 139 140 134 131 139 139 134 135 149 152
Loss ..................................... 192 167 152 150 177 212 249 227 181 146 158 200
System Load ................... 2,152 1,900 1,739 1,715 1,985 2,353 2,727 2,503 2,039 1,677 1,815 2,241
Light Load ........................... 1,987 1,754 1,598 1,553 1,804 2,105 2,474 2,221 1,832 1,512 1,675 2,070
Heavy Load ......................... 2,282 2,010 1,850 1,833 2,140 2,533 2,926 2,726 2,205 1,795 1,939 2,375
Total Load ........................ 2,152 1,900 1,739 1,715 1,985 2,353 2,727 2,503 2,039 1,677 1,815 2,241
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,751 2,581 2,267 2,117 3,379 3,737 4,083 3,506 3,262 2,272 2,489 2,977
Total Peak Load .............. 2,751 2,581 2,267 2,117 3,379 3,737 4,083 3,506 3,262 2,272 2,489 2,977

Monthly Summary1 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)–70th Percentile
Residential .......................... 924 754 645 564 537 598 758 713 560 534 678 964
Commercial ......................... 567 508 480 463 475 514 596 580 523 479 496 592
Irrigation .............................. 2 2 2 91 353 571 664 518 313 47 0 1
Industrial .............................. 340 343 337 323 327 347 347 351 348 353 352 353
Additional Firm .................... 147 142 139 140 134 131 139 139 134 135 149 152
Loss ..................................... 194 169 153 152 178 215 251 229 183 147 160 202
System Load ................... 2,174 1,916 1,757 1,733 2,004 2,377 2,755 2,530 2,062 1,695 1,835 2,265
Light Load ........................... 2,008 1,768 1,614 1,570 1,822 2,127 2,500 2,245 1,852 1,529 1,693 2,092
Heavy Load ......................... 2,317 2,027 1,859 1,852 2,161 2,559 2,957 2,755 2,230 1,827 1,949 2,401
Total Load ........................ 2,174 1,916 1,757 1,733 2,004 2,377 2,755 2,530 2,062 1,695 1,835 2,265
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,774 2,596 2,285 2,135 3,422 3,777 4,139 3,547 3,303 2,291 2,509 3,000
Total Peak Load .............. 2,774 2,596 2,285 2,135 3,422 3,777 4,139 3,547 3,303 2,291 2,509 3,000
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 27
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)–70th Percentile
Residential .......................... 931 757 649 568 542 606 768 723 566 538 683 975
Commercial ......................... 572 512 484 467 480 519 602 586 529 484 501 599
Irrigation .............................. 2 2 2 91 354 573 666 519 314 47 0 1
Industrial .............................. 345 335 342 328 331 352 352 356 353 358 357 358
Additional Firm .................... 146 136 138 139 133 130 138 138 133 134 147 150
Loss ..................................... 195 169 155 153 180 216 254 231 185 149 161 204
System Load ................... 2,191 1,910 1,769 1,747 2,020 2,397 2,780 2,553 2,081 1,710 1,850 2,288
Light Load ........................... 2,024 1,762 1,626 1,582 1,837 2,145 2,522 2,265 1,869 1,542 1,707 2,114
Heavy Load ......................... 2,335 2,019 1,873 1,878 2,165 2,581 3,001 2,761 2,250 1,842 1,965 2,438
Total Load ........................ 2,191 1,910 1,769 1,747 2,020 2,397 2,780 2,553 2,081 1,710 1,850 2,288
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,781 2,605 2,288 2,135 3,463 3,812 4,191 3,582 3,337 2,306 2,517 3,016
Total Peak Load .............. 2,781 2,605 2,288 2,135 3,463 3,812 4,191 3,582 3,337 2,306 2,517 3,016

Monthly Summary1 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)–70th Percentile
Residential .......................... 940 761 654 574 549 615 781 734 574 543 690 988
Commercial ......................... 578 517 489 473 486 526 610 594 537 490 507 607
Irrigation .............................. 2 2 2 91 353 571 664 517 313 47 0 1
Industrial .............................. 350 352 347 333 336 357 357 361 358 363 362 363
Additional Firm .................... 145 140 137 139 133 130 138 138 133 134 146 149
Loss ..................................... 197 171 156 154 182 218 256 234 187 150 163 207
System Load ................... 2,212 1,943 1,786 1,763 2,037 2,417 2,804 2,578 2,101 1,728 1,869 2,315
Light Load ........................... 2,043 1,793 1,641 1,597 1,852 2,163 2,545 2,287 1,888 1,558 1,724 2,139
Heavy Load ......................... 2,346 2,055 1,890 1,896 2,183 2,603 3,028 2,788 2,288 1,850 1,985 2,467
Total Load ........................ 2,212 1,943 1,786 1,763 2,037 2,417 2,804 2,578 2,101 1,728 1,869 2,315
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,800 2,616 2,301 2,147 3,505 3,847 4,244 3,619 3,375 2,324 2,534 3,040
Total Peak Load .............. 2,800 2,616 2,301 2,147 3,505 3,847 4,244 3,619 3,375 2,324 2,534 3,040

Monthly Summary1 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)–70th Percentile
Residential .......................... 950 766 660 581 556 625 794 746 582 550 698 1,000
Commercial ......................... 585 522 496 479 492 534 618 602 545 497 513 615
Irrigation .............................. 2 2 2 91 353 571 664 518 313 47 0 1
Industrial .............................. 355 357 352 337 341 362 362 366 363 368 367 368
Additional Firm .................... 152 147 144 145 138 136 143 143 138 139 154 158
Loss ..................................... 200 173 158 156 184 221 259 236 189 152 165 210
System Load ................... 2,245 1,967 1,811 1,789 2,064 2,448 2,840 2,612 2,130 1,754 1,898 2,352
Light Load ........................... 2,073 1,815 1,664 1,620 1,876 2,191 2,577 2,317 1,914 1,581 1,751 2,172
Heavy Load ......................... 2,380 2,081 1,927 1,912 2,212 2,654 3,047 2,824 2,320 1,878 2,016 2,506
Total Load ........................ 2,245 1,967 1,811 1,789 2,064 2,448 2,840 2,612 2,130 1,754 1,898 2,352
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,836 2,642 2,329 2,174 3,556 3,895 4,308 3,668 3,424 2,351 2,566 3,077
Total Peak Load .............. 2,836 2,642 2,329 2,174 3,556 3,895 4,308 3,668 3,424 2,351 2,566 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 2013 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 28 2013 Integrated Resource Plan—Appendix C
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)–70th Percentile
Residential .......................... 958 770 665 586 562 633 805 757 589 554 705 1,011
Commercial ......................... 592 527 501 485 499 541 627 610 553 504 519 623
Irrigation .............................. 2 2 2 91 354 572 665 519 313 47 0 1
Industrial .............................. 360 362 356 342 345 367 367 371 368 373 372 374
Additional Firm .................... 151 146 143 144 138 135 143 143 138 139 153 156
Loss ..................................... 202 174 160 158 185 223 262 239 192 154 167 212
System Load ................... 2,265 1,981 1,827 1,806 2,083 2,472 2,868 2,639 2,153 1,771 1,917 2,377
Light Load ........................... 2,092 1,828 1,679 1,636 1,893 2,212 2,603 2,341 1,934 1,598 1,768 2,196
Heavy Load ......................... 2,390 2,096 1,944 1,930 2,219 2,679 3,060 2,874 2,313 1,897 2,036 2,507
Total Load ........................ 2,265 1,981 1,827 1,806 2,083 2,472 2,868 2,639 2,153 1,771 1,917 2,377
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,851 2,654 2,339 2,181 3,599 3,936 4,365 3,710 3,465 2,369 2,580 3,097
Total Peak Load .............. 2,851 2,654 2,339 2,181 3,599 3,936 4,365 3,710 3,465 2,369 2,580 3,097

Monthly Summary1 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)–70th Percentile
Residential .......................... 965 773 669 591 568 641 817 767 596 559 710 1,021
Commercial ......................... 599 533 508 491 505 549 635 619 561 510 526 632
Irrigation .............................. 2 2 2 91 353 572 665 518 313 47 0 1
Industrial .............................. 365 355 361 347 350 372 372 376 373 379 377 379
Additional Firm .................... 151 140 142 144 137 135 142 142 137 138 152 156
Loss ..................................... 204 174 161 159 187 225 264 241 194 155 169 214
System Load ................... 2,286 1,977 1,843 1,822 2,100 2,493 2,894 2,664 2,174 1,789 1,935 2,402
Light Load ........................... 2,111 1,824 1,694 1,650 1,910 2,231 2,626 2,364 1,953 1,614 1,785 2,219
Heavy Load ......................... 2,412 2,101 1,951 1,948 2,251 2,685 3,088 2,901 2,336 1,928 2,045 2,534
Total Load ........................ 2,286 1,977 1,843 1,822 2,100 2,493 2,894 2,664 2,174 1,789 1,935 2,402
Peak Load (MW)–95th Percentile
System Peak (1 hour) ..... 2,867 2,652 2,349 2,189 3,642 3,973 4,418 3,748 3,504 2,387 2,594 3,118
Total Peak Load .............. 2,867 2,652 2,349 2,189 3,642 3,973 4,418 3,748 3,504 2,387 2,594 3,118
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 2013 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
2013 Integrated Resource Plan—Appendix C Page 29
Annual Summary
2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Billed Sales (MWh)–70th Percentile
Residential ......................... 5,164,791 5,195,891 5,206,261 5,276,623 5,369,337 5,450,107 5,523,750 5,580,441 5,632,102 5,689,844
Commercial ........................ 3,948,571 4,009,836 4,046,655 4,094,416 4,134,995 4,170,810 4,212,514 4,258,123 4,300,385 4,345,653
Irrigation ............................. 1,881,550 1,892,561 1,899,085 1,881,000 1,879,758 1,886,182 1,890,570 1,895,609 1,898,618 1,895,444
Industrial ............................. 2,334,380 2,402,175 2,466,748 2,523,489 2,568,734 2,609,536 2,653,663 2,698,998 2,743,911 2,788,219
Additional Firm ................... 1,009,771 1,025,200 1,052,800 1,053,500 1,062,300 1,059,600 1,067,700 1,115,100 1,193,100 1,228,700
System Sales.................. 14,339,064 14,525,663 14,671,549 14,829,029 15,015,124 15,176,235 15,348,197 15,548,270 15,768,116 15,947,860
Total Sales ...................... 14,339,064 14,525,663 14,671,549 14,829,029 15,015,124 15,176,235 15,348,197 15,548,270 15,768,116 15,947,860
Generation Month Sales (MWh)–70th Percentile
Residential ......................... 5,167,413 5,197,036 5,211,598 5,300,406 5,375,457 5,455,753 5,528,219 5,602,024 5,636,673 5,695,236
Commercial ........................ 3,951,973 4,011,934 4,049,337 4,107,904 4,137,048 4,173,184 4,215,100 4,272,056 4,302,959 4,348,499
Irrigation ............................. 1,881,554 1,892,564 1,899,078 1,881,038 1,879,761 1,886,184 1,890,572 1,895,649 1,898,617 1,895,444
Industrial ............................. 2,340,228 2,407,744 2,471,642 2,527,392 2,572,253 2,613,342 2,657,573 2,702,871 2,747,733 2,792,033
Additional Firm ................... 1,009,771 1,025,200 1,052,800 1,053,500 1,062,300 1,059,600 1,067,700 1,115,100 1,193,100 1,228,700
System Sales.................. 14,350,940 14,534,478 14,684,455 14,870,240 15,026,819 15,188,062 15,359,163 15,587,701 15,779,082 15,959,913
Total Sales ...................... 14,350,940 14,534,478 14,684,455 14,870,240 15,026,819 15,188,062 15,359,163 15,587,701 15,779,082 15,959,913
Loss .................................... 1,414,977 1,431,581 1,443,654 1,461,800 1,476,685 1,492,948 1,509,490 1,529,225 1,542,768 1,558,213
Required Generation ..... 15,765,916 15,966,059 16,128,108 16,332,040 16,503,504 16,681,010 16,868,653 17,116,926 17,321,850 17,518,125
Average Load (aMW)–70th Percentile
Residential ......................... 590 593 595 603 614 623 631 638 643 650
Commercial ........................ 451 458 462 468 472 476 481 486 491 496
Irrigation ............................. 215 216 217 214 215 215 216 216 217 216
Industrial ............................. 267 275 282 288 294 298 303 308 314 319
Additional Firm ................... 115 117 120 120 121 121 122 127 136 140
Loss .................................... 162 163 165 166 169 170 172 174 176 178
System Load .................. 1,800 1,823 1,841 1,859 1,884 1,904 1,926 1,949 1,977 2,000
Light Load .......................... 1,636 1,657 1,673 1,690 1,712 1,731 1,750 1,771 1,797 1,818
Heavy Load ........................ 1,928 1,953 1,972 1,992 2,019 2,040 2,063 2,087 2,119 2,143
Total Load ....................... 1,800 1,823 1,841 1,859 1,884 1,904 1,926 1,949 1,977 2,000
Peak Load (MW)–95th Percentile
System Peak (1 Hour).... 3,382 3,442 3,495 3,541 3,596 3,651 3,707 3,766 3,827 3,881
Total Peak Load ............. 3,382 3,442 3,495 3,541 3,596 3,651 3,707 3,766 3,827 3,881

Sales and Load Forecast Data Idaho Power Company
Page 30 2013 Integrated Resource Plan—Appendix C
2023 2024 2024 2026 2027 2028 2029 2030 2031 2032
Billed Sales (MWh)–70th Percentile
Residential ......................... 5,758,958 5,813,316 5,860,061 5,932,333 6,006,257 6,062,171 6,132,197 6,209,218 6,273,351 6,333,447
Commercial ........................ 4,395,933 4,435,955 4,472,534 4,525,502 4,579,235 4,625,191 4,681,997 4,744,649 4,804,978 4,867,787
Irrigation ............................. 1,894,663 1,898,303 1,893,243 1,882,293 1,884,974 1,888,949 1,882,964 1,883,789 1,887,937 1,885,770
Industrial ............................. 2,832,435 2,875,947 2,917,139 2,961,183 3,005,317 3,047,482 3,090,882 3,134,512 3,177,840 3,222,016
Additional Firm ................... 1,234,000 1,231,300 1,234,000 1,228,400 1,228,300 1,217,500 1,212,000 1,268,000 1,262,200 1,257,000
System Sales.................. 16,115,989 16,254,821 16,376,977 16,529,711 16,704,083 16,841,293 17,000,039 17,240,168 17,406,305 17,566,020
Total Sales ...................... 16,115,989 16,254,821 16,376,977 16,529,711 16,704,083 16,841,293 17,000,039 17,240,168 17,406,305 17,566,020
Generation Month Sales (MWh)–70th Percentile
Residential ......................... 5,763,317 5,834,947 5,865,721 5,938,129 6,010,781 6,085,880 6,138,263 6,214,376 6,278,234 6,356,880
Commercial ........................ 4,398,233 4,449,963 4,475,535 4,528,549 4,581,867 4,640,688 4,685,537 4,748,069 4,808,536 4,884,307
Irrigation ............................. 1,894,665 1,898,340 1,893,239 1,882,294 1,884,976 1,888,985 1,882,964 1,883,791 1,887,936 1,885,808
Industrial ............................. 2,836,188 2,879,500 2,920,938 2,964,990 3,008,954 3,051,226 3,094,645 3,138,249 3,181,650 3,225,818
Additional Firm ................... 1,234,000 1,231,300 1,234,000 1,228,400 1,228,300 1,217,500 1,212,000 1,268,000 1,262,200 1,257,000
System Sales.................. 16,126,403 16,294,050 16,389,434 16,542,362 16,714,878 16,884,279 17,013,410 17,252,484 17,418,556 17,609,813
Total Sales ...................... 16,126,403 16,294,050 16,389,434 16,542,362 16,714,878 16,884,279 17,013,410 17,252,484 17,418,556 17,609,813
Loss .................................... 1,574,463 1,591,342 1,600,133 1,615,595 1,632,909 1,650,617 1,663,620 1,683,930 1,700,984 1,720,590
Required Generation ..... 17,700,866 17,885,392 17,989,567 18,157,957 18,347,787 18,534,896 18,677,030 18,936,415 19,119,540 19,330,402
Average Load (aMW)–70th Percentile
Residential ......................... 658 664 670 678 686 693 701 709 717 724
Commercial ........................ 502 507 511 517 523 528 535 542 549 556
Irrigation ............................. 216 216 216 215 215 215 215 215 216 215
Industrial ............................. 324 328 333 338 343 347 353 358 363 367
Additional Firm ................... 141 140 141 140 140 139 138 145 144 143
Loss .................................... 180 181 183 184 186 188 190 192 194 196
System Load .................. 2,021 2,036 2,054 2,073 2,094 2,110 2,132 2,162 2,183 2,201
Light Load .......................... 1,837 1,851 1,867 1,884 1,904 1,918 1,938 1,965 1,984 2,000
Heavy Load ........................ 2,166 2,181 2,200 2,221 2,244 2,261 2,284 2,316 2,332 2,351
Total Load ....................... 2,021 2,036 2,054 2,073 2,094 2,110 2,132 2,162 2,183 2,201
Peak Load (MW)–95th Percentile
System Peak (1 Hour).... 3,935 3,987 4,033 4,083 4,139 4,191 4,244 4,308 4,365 4,418
Total Peak Load ............. 3,935 3,987 4,033 4,083 4,139 4,191 4,244 4,308 4,365 4,418

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 31

LOAD AND RESOURCE BALANCE DATA
Monthly Average Energy Load and Resource Balance
1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013
Existing DSM (EE) 7 7 7 8 8 8 8 8 8 8 7 7
Load Forecast (70th% w/DSM) (1,864) (1,684) (1,511) (1,484) (1,740) (2,067) (2,390) (2,178) (1,762) (1,437) (1,555) (1,902)
Existing Resources
Coal 933 933 806 699 841 915 933 933 933 933 932 933
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 579 603 595 676 868 703 517 383 436 413 364 469
Hydro (70th%)—Other 216 234 215 236 328 337 278 251 224 219 202 208
Shoshone Falls Upgrade (70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 72 0 0 0 0 0
Total Hydro (70th%) 795 837 811 912 1,195 1,040 867 634 660 632 566 677
CSPP (PURPA) 201 207 212 262 306 297 263 241 247 235 242 199
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 62 74 54 54 72 73 75 75 61 43 55 82
Firm Pacific NW Import Capability 0 0 0 0 205 292 194 264 68 0 0 0
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,539 2,342 1,882 1,926 2,620 3,126 2,837 2,662 2,249 2,127 2,084 2,431
Monthly Surplus/Deficit 675 657 371 442 880 1,059 447 483 487 690 529 529
2013 IRP DSM
Irrigation 0 0 0 1 2 3 3 3 1 0 0 0
Commercial/Industrial 6 6 6 6 6 7 7 7 6 6 6 6
Residential 0 0 0 0 0 0 0 0 0 0 0 0
Total New DSM (aMW) 6 6 6 7 9 10 10 9 8 7 6 7
Monthly Surplus/Deficit 682 664 378 449 889 1,068 457 493 495 697 535 535
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 682 664 378 449 889 1,068 457 493 495 697 535 535

Load and Resource Balance Data Idaho Power Company
Page 32 2013 Integrated Resource Plan—Appendix C
Monthly Average Energy Load and Resource Balance (continued)
1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014
Existing DSM (EE) 14 14 14 15 16 16 16 16 15 14 14 14
Load Forecast (70th% w/DSM) (1,887) (1,702) (1,530) (1,503) (1,763) (2,090) (2,421) (2,208) (1,788) (1,457) (1,576) (1,923)
Existing Resources
Coal 933 933 779 668 853 915 932 932 932 932 931 932
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 575 602 594 673 867 701 516 381 435 410 364 466
Hydro (70th%)—Other 215 221 213 228 327 336 278 250 223 219 201 207
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 72 0 0 0 0 0
Total Hydro (70th%) 790 823 806 901 1,194 1,037 865 632 658 629 565 673
CSPP (PURPA) 203 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 62 74 54 54 72 73 75 75 61 43 55 82
Firm Pacific NW Import Capability 0 0 0 0 230 352 237 277 113 0 0 1
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,536 2,341 1,863 1,896 2,667 3,195 2,889 2,683 2,302 2,134 2,094 2,438
Monthly Surplus/Deficit 650 639 333 392 904 1,104 468 475 515 677 518 515
2013 IRP DSM
Irrigation 0 0 0 1 4 6 6 5 3 0 0 0
Commercial/Industrial 13 13 13 13 13 13 13 13 13 13 13 13
Residential 0 0 0 0 0 0 0 0 0 0 0 0
Total New DSM (aMW) 13 13 13 14 17 19 20 19 16 14 13 13
Monthly Surplus/Deficit 663 653 347 407 921 1,124 487 494 530 691 531 528
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 663 653 347 407 921 1,124 487 494 530 691 531 528

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 33
Monthly Average Energy Load and Resource Balance (continued)
1/2015 2/2015 3/2015 4/2015 5/2015 6/2015 7/2015 8/2015 9/2015 10/2015 11/2015 12/2015
Existing DSM (EE) 21 21 21 22 24 24 24 23 23 22 21 21
Load Forecast (70th% w/DSM) (1,903) (1,714) (1,544) (1,519) (1,780) (2,112) (2,445) (2,231) (1,807) (1,473) (1,593) (1,949)
Existing Resources
Coal 932 932 832 648 687 812 932 932 932 932 931 932
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 582 619 598 715 869 705 516 381 434 418 363 479
Hydro (70th%)—Other 218 258 214 259 331 340 278 251 224 221 202 209
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 72 0 0 0 0 0
Total Hydro (70th%) 799 877 813 974 1,199 1,045 865 632 658 639 566 688
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 62 74 54 54 72 73 75 75 61 43 55 82
Firm Pacific NW Import Capability 0 0 0 0 276 342 237 274 147 0 0 15
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,557 2,395 1,922 1,949 2,552 3,089 2,889 2,681 2,336 2,145 2,095 2,467
Monthly Surplus/Deficit 654 681 378 430 771 978 444 450 529 671 502 518
2013 IRP DSM
Irrigation 0 0 0 2 6 8 8 7 4 1 0 0
Commercial/Industrial 19 19 19 19 19 20 20 20 19 19 19 19
Residential 1 1 1 1 1 1 1 1 1 1 1 1
Total New DSM (aMW) 20 20 20 21 26 28 29 27 23 20 20 20
Monthly Surplus/Deficit 673 700 398 451 797 1,006 473 478 552 691 521 538
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 673 700 398 451 797 1,006 473 478 552 691 521 538

Load and Resource Balance Data Idaho Power Company
Page 34 2013 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
Existing DSM (EE) 26 26 26 27 29 30 30 29 28 26 26 26
Load Forecast (70th% w/DSM) (1,927) (1,717) (1,562) (1,536) (1,797) (2,129) (2,465) (2,251) (1,826) (1,492) (1,614) (1,976)
Existing Resources
Coal 932 932 703 686 716 839 938 938 938 938 937 938
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 581 617 599 712 872 704 515 351 432 416 364 488
Hydro (70th%)—Other 218 283 214 261 330 340 277 206 224 221 202 208
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 798 900 813 973 1,202 1,043 791 556 656 637 566 696
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 0 0 0 0 314 342 237 272 178 0 0 34
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,551 2,412 1,807 1,997 2,611 3,104 2,811 2,602 2,368 2,168 2,117 2,497
Monthly Surplus/Deficit 624 694 244 461 815 975 347 351 542 675 504 520
2013 IRP DSM
Irrigation 0 0 0 2 7 9 10 8 4 1 0 0
Commercial/Industrial 25 24 24 24 25 25 25 25 24 24 24 24
Residential 2 2 2 2 2 2 2 2 2 2 2 2
Total New DSM (aMW) 27 26 26 28 33 36 37 35 31 27 26 26
Monthly Surplus/Deficit 651 721 270 489 848 1,012 383 386 572 703 530 547
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 651 721 270 489 848 1,012 383 386 572 703 530 547

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 35
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
Existing DSM (EE) 30 30 30 31 34 35 35 34 33 30 30 30
Load Forecast (70th% w/DSM) (1,952) (1,752) (1,582) (1,556) (1,817) (2,152) (2,493) (2,278) (1,849) (1,513) (1,636) (2,004)
Existing Resources
Coal 938 938 940 781 709 835 944 944 944 944 943 944
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 580 616 596 700 867 702 513 349 431 414 364 487
Hydro (70th%)—Other 217 275 206 251 330 338 276 205 223 220 201 208
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 797 891 802 951 1,197 1,041 789 554 654 634 565 694
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 0 0 0 0 359 347 237 269 219 0 0 61
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,555 2,409 2,032 2,070 2,644 3,102 2,816 2,603 2,412 2,171 2,123 2,528
Monthly Surplus/Deficit 603 656 449 514 828 950 323 325 564 658 487 524
2013 IRP DSM
Irrigation 0 0 0 2 8 11 11 9 5 1 0 0
Commercial/Industrial 29 29 29 29 30 30 30 30 29 29 29 30
Residential 4 4 4 4 4 3 3 3 4 4 4 4
Total New DSM (aMW) 33 33 33 35 41 44 45 43 38 34 33 33
Monthly Surplus/Deficit 636 689 482 550 868 994 368 368 602 692 520 558
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 636 689 482 550 868 994 368 368 602 692 520 558

Load and Resource Balance Data Idaho Power Company
Page 36 2013 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
Existing DSM (EE) 34 34 34 35 39 40 40 39 37 34 34 34
Load Forecast (70th% w/DSM) (1,974) (1,768) (1,599) (1,572) (1,835) (2,175) (2,520) (2,303) (1,869) (1,529) (1,654) (2,029)
Existing Resources
Coal 944 944 881 731 743 922 948 948 948 948 947 948
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 579 606 588 699 866 694 512 348 430 410 364 480
Hydro (70th%)—Other 215 233 206 250 330 337 276 204 222 219 201 207
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 795 839 794 949 1,196 1,032 788 552 652 630 564 687
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 0 0 0 0 385 342 237 267 257 0 0 86
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,559 2,363 1,965 2,017 2,704 3,175 2,818 2,603 2,452 2,170 2,126 2,550
Monthly Surplus/Deficit 585 595 367 445 869 1,000 298 299 583 641 472 521
2013 IRP DSM
Irrigation 0 0 0 2 9 12 13 11 6 1 0 0
Commercial/Industrial 35 35 35 35 35 36 36 36 35 35 35 35
Residential 7 7 7 7 7 6 6 6 7 7 7 7
Total New DSM (aMW) 42 42 41 44 51 55 55 53 48 42 42 42
Monthly Surplus/Deficit 627 636 408 489 920 1,055 353 352 630 683 513 563
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 827 836 608 989 1,420 1,555 853 852 1,130 883 713 763

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 37
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
Existing DSM (EE) 37 37 37 39 44 45 45 44 41 38 37 37
Load Forecast (70th% w/DSM) (1,996) (1,785) (1,616) (1,590) (1,854) (2,198) (2,547) (2,330) (1,891) (1,548) (1,674) (2,054)
Existing Resources
Coal 948 948 901 833 731 865 954 954 954 954 953 954
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 578 602 588 695 865 690 511 347 428 399 363 474
Hydro (70th%)—Other 215 223 200 243 329 337 275 203 221 219 199 207
Shoshone Falls Upgrade(70th%) 0 0 0 0 0 0 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 793 825 788 937 1,195 1,027 788 549 649 618 564 684
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 0 0 0 0 384 342 237 265 270 0 0 111
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,561 2,353 1,979 2,109 2,690 3,113 2,825 2,604 2,468 2,164 2,131 2,577
Monthly Surplus/Deficit 565 568 363 519 836 915 277 274 576 617 457 524
2013 IRP DSM
Irrigation 0 0 0 3 10 14 15 12 7 1 0 0
Commercial/Industrial 40 39 40 39 40 41 41 41 40 39 40 40
Residential 10 10 10 10 10 9 9 9 10 10 10 10
Total New DSM (aMW) 49 49 49 52 60 64 65 62 56 50 49 50
Monthly Surplus/Deficit 614 617 412 571 895 979 342 337 633 667 507 573
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 814 817 612 1,071 1,395 1,479 842 837 1,133 867 707 773

Load and Resource Balance Data Idaho Power Company
Page 38 2013 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
Existing DSM (EE) 42 42 42 44 49 50 51 49 46 43 42 42
Load Forecast (70th% w/DSM) (2,022) (1,789) (1,637) (1,611) (1,877) (2,225) (2,578) (2,359) (1,916) (1,569) (1,698) (2,083)
Existing Resources
Coal 948 948 949 762 686 910 954 954 954 954 954 954
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 577 599 588 691 865 687 510 345 427 395 364 469
Hydro (70th%)—Other 214 220 198 236 329 336 274 202 220 218 198 206
Shoshone Falls Upgrade(70th%) 6 15 0 1 15 17 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 798 834 786 929 1,208 1,039 786 547 647 613 563 677
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 0 0 0 0 383 342 237 262 269 0 4 139
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,566 2,361 2,025 2,029 2,657 3,170 2,822 2,599 2,464 2,160 2,136 2,598
Monthly Surplus/Deficit 543 572 388 418 781 945 245 240 549 591 439 515
2013 IRP DSM
Irrigation 0 0 0 3 12 16 17 14 8 1 0 0
Commercial/Industrial 45 45 45 45 46 47 47 47 45 45 46 45
Residential 9 9 9 9 9 8 8 8 9 9 9 9
Total New DSM (aMW) 54 54 54 57 66 71 72 69 62 55 55 54
Monthly Surplus/Deficit 598 626 443 475 847 1,017 317 309 610 647 493 570
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 798 826 643 975 1,347 1,517 817 809 1,110 847 693 770

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 39
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
Existing DSM (EE) 45 45 45 48 54 55 56 54 51 46 45 45
Load Forecast (70th% w/DSM) (2,051) (1,828) (1,660) (1,635) (1,901) (2,253) (2,609) (2,389) (1,942) (1,592) (1,725) (2,117)
Existing Resources
Coal 894 863 811 624 658 791 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 576 593 588 687 864 684 508 344 425 395 364 479
Hydro (70th%)—Other 213 219 196 238 327 333 273 201 219 217 197 205
Shoshone Falls Upgrade(70th%) 6 12 0 1 15 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 795 824 784 926 1,206 1,033 784 544 643 612 562 686
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 87 0 0 0 434 395 290 313 320 0 83 225
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,596 2,267 1,884 1,888 2,678 3,099 2,819 2,593 2,458 2,104 2,159 2,639
Monthly Surplus/Deficit 545 439 224 253 776 845 209 204 516 512 435 522
2013 IRP DSM
Irrigation 0 0 0 4 13 19 20 16 9 2 0 0
Commercial/Industrial 51 51 50 51 52 53 53 53 51 51 51 51
Residential 9 9 9 9 9 8 8 8 9 9 9 9
Total New DSM (aMW) 60 60 60 64 74 80 80 77 69 62 60 60
Monthly Surplus/Deficit 605 499 284 317 851 925 290 281 585 574 495 582
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 805 699 484 817 1,351 1,425 790 781 1,085 774 695 782

Load and Resource Balance Data Idaho Power Company
Page 40 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 45 45 45 48 54 55 56 54 51 46 45 45
Load Forecast (70th% w/DSM) (2,051) (1,828) (1,660) (1,635) (1,901) (2,253) (2,609) (2,389) (1,942) (1,592) (1,725) (2,117)
Existing Resources
Coal 894 863 811 624 658 791 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 576 593 588 687 864 684 508 344 425 395 364 479
Hydro (70th%)—Other 213 219 196 238 327 333 273 201 219 217 197 205
Shoshone Falls Upgrade(70th%) 6 12 0 1 15 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 795 824 784 926 1,206 1,033 784 544 643 612 562 686
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 87 0 0 0 434 395 290 313 320 0 83 225
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,596 2,267 1,884 1,888 2,678 3,099 2,819 2,593 2,458 2,104 2,159 2,639
Monthly Surplus/Deficit 545 439 224 253 776 845 209 204 516 512 435 522
2013 IRP DSM
Irrigation 0 0 0 4 13 19 20 16 9 2 0 0
Commercial/Industrial 51 51 50 51 52 53 53 53 51 51 51 51
Residential 9 9 9 9 9 8 8 8 9 9 9 9
Total New DSM (aMW) 60 60 60 64 74 80 80 77 69 62 60 60
Monthly Surplus/Deficit 605 499 284 317 851 925 290 281 585 574 495 582
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 805 699 484 817 1,351 1,425 790 781 1,085 774 695 782

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 41
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
Existing DSM (EE) 49 49 49 51 58 60 60 58 55 50 49 49
Load Forecast (70th% w/DSM) (2,075) (1,846) (1,680) (1,654) (1,921) (2,276) (2,635) (2,414) (1,964) (1,612) (1,747) (2,147)
Existing Resources
Coal 894 863 784 702 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 575 592 588 685 863 682 507 342 423 391 364 471
Hydro (70th%)—Other 212 218 194 233 326 332 273 200 218 216 196 204
Shoshone Falls Upgrade(70th%) 6 9 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 793 819 782 919 1,204 1,031 782 542 641 607 561 677
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 113 0 0 0 433 349 237 308 318 0 103 254
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,620 2,262 1,856 1,959 2,747 3,060 2,763 2,585 2,453 2,099 2,178 2,659
Monthly Surplus/Deficit 544 416 177 305 826 784 128 171 490 488 431 512
2013 IRP DSM
Irrigation 0 0 0 4 15 22 22 19 10 2 0 0
Commercial/Industrial 59 58 58 58 59 60 60 60 58 58 58 58
Residential 9 9 10 10 9 8 8 8 9 9 9 10
Total New DSM (aMW) 68 67 67 72 84 90 91 88 78 70 68 67
Monthly Surplus/Deficit 613 483 244 376 910 875 219 258 567 557 499 580
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 813 683 444 876 1,410 1,375 719 758 1,067 757 699 780

Load and Resource Balance Data Idaho Power Company
Page 42 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 52 52 52 55 62 64 65 62 58 53 52 52
Load Forecast (70th% w/DSM) (2,097) (1,862) (1,697) (1,672) (1,940) (2,298) (2,662) (2,440) (1,985) (1,630) (1,766) (2,171)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 574 591 587 682 862 681 505 341 422 387 364 463
Hydro (70th%)—Other 211 214 193 223 326 332 272 199 217 216 195 202
Shoshone Falls Upgrade(70th%) 6 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 791 812 780 905 1,202 1,029 779 539 638 602 560 668
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 136 0 0 0 431 346 237 306 316 0 123 291
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,641 2,254 1,848 1,905 2,743 3,055 2,761 2,581 2,449 2,094 2,198 2,687
Monthly Surplus/Deficit 543 392 151 234 804 757 99 141 464 464 431 516
2013 IRP DSM
Irrigation 0 0 0 5 18 25 26 22 11 2 0 0
Commercial/Industrial 64 64 64 64 65 67 67 67 64 64 64 65
Residential 10 10 10 10 10 9 9 9 10 10 10 10
Total New DSM (aMW) 74 74 73 79 92 100 101 97 85 76 74 74
Monthly Surplus/Deficit 617 466 224 313 896 857 200 237 549 540 505 590
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 817 666 424 813 1,396 1,357 700 737 1,049 740 705 790

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 43
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
Existing DSM (EE) 55 54 55 57 65 68 68 66 62 56 55 55
Load Forecast (70th% w/DSM) (2,115) (1,857) (1,710) (1,686) (1,955) (2,318) (2,685) (2,462) (2,004) (1,645) (1,782) (2,191)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 573 590 587 677 861 680 504 339 421 383 364 458
Hydro (70th%)—Other 209 212 191 211 325 331 271 198 216 215 194 201
Shoshone Falls Upgrade(70th%) 5 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 787 809 778 889 1,201 1,027 777 537 637 598 559 662
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 143 0 0 0 430 342 237 303 315 0 132 312
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,643 2,251 1,846 1,889 2,741 3,049 2,759 2,575 2,446 2,090 2,206 2,702
Monthly Surplus/Deficit 529 394 135 203 785 731 74 113 442 445 424 511
2013 IRP DSM
Irrigation 0 0 0 6 20 28 29 25 13 2 0 0
Commercial/Industrial 71 71 71 71 71 74 74 74 72 71 71 72
Residential 12 12 12 12 12 11 11 11 12 12 12 12
Total New DSM (aMW) 84 83 84 89 104 113 114 109 97 86 84 84
Monthly Surplus/Deficit 612 478 219 292 889 844 188 222 540 531 508 595
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 812 678 419 792 1,389 1,344 688 722 1,040 731 708 795

Load and Resource Balance Data Idaho Power Company
Page 44 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 57 57 57 60 68 71 72 69 64 58 57 57
Load Forecast (70th% w/DSM) (2,130) (1,885) (1,723) (1,699) (1,969) (2,334) (2,705) (2,481) (2,020) (1,659) (1,796) (2,215)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 572 589 587 667 861 678 502 338 420 379 365 457
Hydro (70th%)—Other 208 212 190 210 325 330 270 197 215 214 193 200
Shoshone Falls Upgrade(70th%) 5 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 784 807 777 877 1,200 1,025 775 535 635 593 559 660
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 160 0 0 0 428 342 237 300 313 0 135 321
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,658 2,249 1,845 1,877 2,737 3,047 2,757 2,570 2,442 2,085 2,208 2,709
Monthly Surplus/Deficit 528 365 122 178 769 713 52 89 422 426 412 494
2013 IRP DSM
Irrigation 0 0 0 6 23 32 33 28 15 3 0 0
Commercial/Industrial 77 77 77 77 77 80 80 80 77 77 78 77
Residential 16 16 16 16 16 14 14 14 16 16 16 16
Total New DSM (aMW) 93 93 93 99 116 126 127 122 108 96 94 93
Monthly Surplus/Deficit 621 458 216 278 885 839 179 211 530 522 506 587
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 821 658 416 778 1,385 1,339 679 711 1,030 722 706 787

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 45
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
Existing DSM (EE) 59 59 59 62 71 74 75 72 67 60 59 59
Load Forecast (70th% w/DSM) (2,152) (1,900) (1,739) (1,715) (1,985) (2,353) (2,727) (2,503) (2,039) (1,677) (1,815) (2,241)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 570 588 587 666 860 677 501 336 419 375 365 456
Hydro (70th%)—Other 205 211 189 209 325 329 269 196 214 213 192 200
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 779 805 775 875 1,199 1,022 773 532 632 588 558 659
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 183 0 0 0 427 342 237 298 311 0 154 319
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,676 2,247 1,843 1,876 2,735 3,045 2,754 2,565 2,438 2,081 2,226 2,706
Monthly Surplus/Deficit 524 347 104 161 750 692 28 62 399 404 411 465
2013 IRP DSM
Irrigation 0 0 0 7 26 36 38 32 17 3 0 0
Commercial/Industrial 83 83 83 83 84 86 86 86 83 83 84 83
Residential 21 21 21 21 21 18 18 18 21 21 21 21
Total New DSM (aMW) 104 104 104 111 131 141 142 136 120 107 105 104
Monthly Surplus/Deficit 628 451 208 271 881 833 170 198 519 511 516 569
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 828 651 408 771 1,381 1,333 670 698 1,019 711 716 769

Load and Resource Balance Data Idaho Power Company
Page 46 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 61 61 61 64 74 77 77 74 69 63 61 61
Load Forecast (70th% w/DSM) (2,174) (1,916) (1,757) (1,733) (2,004) (2,377) (2,755) (2,530) (2,062) (1,695) (1,835) (2,265)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 218 0 0 0 425 342 237 295 308 0 174 317
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,700 2,245 1,841 1,874 2,731 3,042 2,752 2,560 2,433 2,077 2,246 2,702
Monthly Surplus/Deficit 526 329 84 141 727 666 (3) 29 371 382 411 437
2013 IRP DSM
Irrigation 0 0 0 8 29 41 43 36 19 4 0 0
Commercial/Industrial 89 88 88 88 90 92 92 92 89 89 89 89
Residential 27 27 27 27 26 23 23 23 27 27 27 27
Total New DSM (aMW) 116 115 115 123 146 156 158 151 134 119 115 115
Monthly Surplus/Deficit 642 444 199 264 873 822 155 181 505 501 526 552
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 842 644 399 764 1,373 1,322 655 681 1,005 701 726 752

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 47
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
Existing DSM (EE) 63 62 62 66 75 79 79 76 71 64 63 63
Load Forecast (70th% w/DSM) (2,191) (1,910) (1,769) (1,747) (2,020) (2,397) (2,780) (2,553) (2,081) (1,710) (1,850) (2,288)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 236 0 7 0 423 342 237 293 306 0 182 314
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,718 2,245 1,848 1,874 2,729 3,042 2,752 2,558 2,431 2,077 2,254 2,699
Monthly Surplus/Deficit 527 336 78 127 709 646 (27) 4 350 367 403 410
2013 IRP DSM
Irrigation 0 0 0 9 33 46 48 40 21 4 0 0
Commercial/Industrial 96 94 94 95 96 98 98 98 95 95 95 96
Residential 33 33 33 33 33 29 29 29 33 33 33 33
Total New DSM (aMW) 128 127 127 137 161 174 175 168 149 132 128 128
Monthly Surplus/Deficit 655 463 206 264 871 819 148 172 499 499 531 538
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 855 663 406 764 1,371 1,319 648 672 999 699 731 738

Load and Resource Balance Data Idaho Power Company
Page 48 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 64 64 64 68 77 80 81 78 73 65 64 64
Load Forecast (70th% w/DSM) (2,212) (1,943) (1,786) (1,763) (2,037) (2,417) (2,804) (2,578) (2,101) (1,728) (1,869) (2,315)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 247 0 24 0 421 342 237 290 304 0 199 312
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,729 2,245 1,865 1,874 2,727 3,042 2,752 2,555 2,429 2,077 2,271 2,697
Monthly Surplus/Deficit 517 303 79 111 690 625 (52) (23) 327 349 402 381
2013 IRP DSM
Irrigation 0 0 0 10 37 52 54 45 24 5 0 0
Commercial/Industrial 100 100 100 100 101 104 104 104 101 100 100 101
Residential 38 38 38 38 37 33 33 33 37 38 38 37
Total New DSM (aMW) 138 138 137 148 175 189 191 182 163 142 138 139
Monthly Surplus/Deficit 655 440 217 259 866 814 138 160 490 491 540 520
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 855 640 417 759 1,366 1,314 638 660 990 691 740 720

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 49
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
Existing DSM (EE) 65 65 65 69 79 82 83 80 74 67 65 66
Load Forecast (70th% w/DSM) (2,245) (1,967) (1,811) (1,789) (2,064) (2,448) (2,840) (2,612) (2,130) (1,754) (1,898) (2,352)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 281 0 61 0 419 342 237 287 302 0 231 310
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,763 2,245 1,902 1,874 2,725 3,042 2,752 2,552 2,427 2,077 2,303 2,695
Monthly Surplus/Deficit 519 278 90 85 662 594 (87) (60) 296 323 404 343
2013 IRP DSM
Irrigation 0 0 0 11 38 54 56 47 25 5 0 0
Commercial/Industrial 105 105 105 105 105 109 109 109 106 105 105 106
Residential 43 43 43 43 43 38 38 38 43 43 43 43
Total New DSM (aMW) 148 148 148 158 186 200 202 194 174 152 148 149
Monthly Surplus/Deficit 667 426 239 243 848 795 115 134 470 476 553 492
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 867 626 439 743 1,348 1,295 615 634 970 676 753 692

Load and Resource Balance Data Idaho Power Company
Page 50 2013 Integrated Resource Plan—Appendix C
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
Existing DSM (EE) 66 66 66 70 80 83 84 81 75 68 66 66
Load Forecast (70th% w/DSM) (2,265) (1,981) (1,827) (1,806) (2,083) (2,472) (2,868) (2,639) (2,153) (1,771) (1,917) (2,377)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 37 36 34 31 31 35 37 26 31 41 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 68 67 65 62 62 65 68 57 62 72 78
Firm Pacific NW Import Capability 291 12 78 15 418 342 237 285 300 0 245 308
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,773 2,257 1,919 1,889 2,724 3,042 2,752 2,550 2,425 2,077 2,317 2,693
Monthly Surplus/Deficit 508 276 92 83 642 571 (116) (89) 272 306 400 316
2013 IRP DSM
Irrigation 0 0 0 11 40 56 58 49 26 5 0 0
Commercial/Industrial 110 110 110 109 110 114 114 114 110 109 111 110
Residential 48 48 48 48 48 42 42 42 48 48 47 48
Total New DSM (aMW) 158 157 158 168 198 212 214 205 184 162 159 158
Monthly Surplus/Deficit 666 433 249 252 840 783 98 116 455 468 559 474
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 866 633 449 752 1,340 1,283 598 616 955 668 759 674

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 51
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
Existing DSM (EE) 67 67 67 70 81 84 84 81 75 68 67 67
Load Forecast (70th% w/DSM) (2,286) (1,977) (1,843) (1,822) (2,100) (2,493) (2,894) (2,664) (2,174) (1,789) (1,935) (2,402)
Existing Resources
Coal 894 863 777 662 730 801 900 900 900 900 900 900
Gas (Langley Gulch) 296 291 0 0 0 278 276 277 279 284 289 296
Hydro (70th%)—HCC 562 587 586 665 859 676 500 335 417 372 365 455
Hydro (70th%)—Other 203 211 187 208 324 328 269 195 213 213 192 199
Shoshone Falls Upgrade(70th%) 4 6 0 0 14 16 2 0 0 0 1 3
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (70th%) 769 803 773 874 1,197 1,020 771 529 630 585 557 657
CSPP (PURPA) 214 221 223 273 317 308 275 253 259 246 254 210
PPAs
Elkhorn Valley Wind 37 34 36 33 31 30 35 37 25 31 40 47
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 57 65 67 64 62 61 65 68 56 62 71 78
Firm Pacific NW Import Capability 313 10 85 33 416 342 237 281 299 0 259 306
Gas Peakers 253 0 0 0 0 231 229 238 0 0 0 244
Existing Resource Subtotal 2,795 2,252 1,926 1,906 2,722 3,041 2,752 2,546 2,423 2,077 2,329 2,691
Monthly Surplus/Deficit 510 275 83 84 622 548 (142) (118) 249 288 394 288
2013 IRP DSM
Irrigation 0 0 0 12 42 59 61 51 27 5 0 0
Commercial/Industrial 115 115 114 114 117 119 119 119 115 115 115 115
Residential 52 52 52 52 52 46 46 46 52 52 52 52
Total New DSM (aMW) 167 167 167 178 210 224 226 216 194 172 167 167
Monthly Surplus/Deficit 677 442 249 262 832 772 84 98 443 460 561 456
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 877 642 449 762 1,332 1,272 584 598 943 660 761 656

Load and Resource Balance Data Idaho Power Company
Page 52 2013 Integrated Resource Plan—Appendix C
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, and IRP DSM

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

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W
Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 53
Peak-Hour Load and Resource Balance
1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013
Load Forecast (95th% w/no DSM) (2,513) (2,392) (2,099) (1,978) (2,813) (3,272) (3,390) (3,035) (2,785) (2,033) (2,274) (2,690)
Existing DSM (EE) 7 7 7 8 8 8 8 8 8 8 7 7
Peak-Hour Forecast w/DSM (EE) (2,505) (2,384) (2,092) (1,971) (2,805) (3,264) (3,382) (3,027) (2,778) (2,026) (2,267) (2,683)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,505) (2,384) (2,092) (1,971) (2,805) (3,264) (3,382) (3,027) (2,778) (2,026) (2,267) (2,683)
Existing Resources
Coal 1,024 1,024 1,024 1,024 966 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 854 1,085 1,023 1,062 1,133 1,027 916 878 761 887 673 938
Hydro (90th%)—Other 245 246 224 244 347 360 304 270 255 249 240 245
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 48 0 0 0 0 0
Total Hydro (90th%) 1,099 1,331 1,247 1,306 1,480 1,387 1,268 1,148 1,016 1,136 912 1,183
CSPP (PURPA) 73 76 82 117 163 171 177 168 155 117 84 77
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
Clatskanie Exchange–Take 4 4 4 6 6 7 6 4 3 1 2 3
Clatskanie Exchange– Return 0 0 (10) (15) 0 0 0 0 0 (10) (15) 0
Total PPAs 29 40 30 27 42 43 41 40 39 27 23 39
Firm Pacific NW Import Capability 0 0 0 0 205 292 194 264 68 0 0 0
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,940 3,186 3,099 3,189 3,572 3,632 3,420 3,359 3,018 3,020 2,759 3,038
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 1 2 3 3 3 1 0 0 0
Commercial 6 6 6 6 6 7 7 7 6 6 6 6
Residential 0 0 0 0 0 0 0 0 0 0 0 0
Total New DSM Peak Reduction 6 6 6 7 9 10 10 9 8 7 6 7
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 441 809 1,013 1,225 776 378 48 342 248 1,001 499 362

Load and Resource Balance Data Idaho Power Company
Page 54 2013 Integrated Resource Plan—Appendix C
Peak-Hour Load and Resource Balance (continued)
1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014
Load Forecast (95th% w/no DSM) (2,548) (2,417) (2,129) (2,010) (2,868) (3,325) (3,458) (3,087) (2,837) (2,061) (2,303) (2,718)
Existing DSM (EE) 14 14 14 15 16 16 16 16 15 14 14 14
Peak-Hour Forecast w/DSM (EE) (2,534) (2,403) (2,115) (1,996) (2,852) (3,310) (3,442) (3,071) (2,822) (2,047) (2,289) (2,704)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,534) (2,403) (2,115) (1,996) (2,852) (3,310) (3,442) (3,071) (2,822) (2,047) (2,289) (2,704)
Existing Resources
Coal 1,024 1,024 1,024 966 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 852 1,078 1,017 1,061 1,132 1,024 914 874 758 880 673 935
Hydro (90th%)—Other 244 245 224 243 343 356 303 269 255 248 238 244
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 48 0 0 0 0 0
Total Hydro (90th%) 1,097 1,323 1,241 1,304 1,475 1,380 1,265 1,143 1,012 1,129 911 1,179
CSPP (PURPA) 75 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
Clatskanie Exchange–Take 4 4 4 6 6 7 6 4 3 1 2 3
Clatskanie Exchange– Return 0 0 (10) (15) 0 0 0 0 0 (10) (15) 0
Total PPAs 29 40 30 27 42 43 41 40 39 27 23 39
Firm Pacific NW Import Capability 0 0 0 0 230 352 237 277 113 0 0 1
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,940 3,192 3,103 3,141 3,661 3,697 3,471 3,379 3,070 3,024 2,769 3,047
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 1 4 6 6 5 3 0 0 0
Commercial 13 13 13 13 13 13 13 13 13 13 13 13
Residential 0 0 0 0 0 0 0 0 0 0 0 0
Total New DSM Peak Reduction 13 13 13 14 17 19 20 19 16 14 13 13
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 419 803 1,001 1,159 825 406 49 326 265 991 493 356

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 55
Peak-Hour Load and Resource Balance (continued)
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 (95th% w/no DSM) (2,552) (2,435) (2,129) (2,002) (2,922) (3,369) (3,520) (3,129) (2,879) (2,087) (2,310) (2,739)
Existing DSM (EE) 21 21 21 22 24 24 24 23 23 22 21 21
Peak-Hour Forecast w/DSM (EE) (2,530) (2,413) (2,108) (1,980) (2,898) (3,345) (3,495) (3,106) (2,856) (2,065) (2,289) (2,718)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,530) (2,413) (2,108) (1,980) (2,898) (3,345) (3,495) (3,106) (2,856) (2,065) (2,289) (2,718)
Existing Resources
Coal 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 855 1,080 1,029 1,062 1,134 1,025 914 873 756 886 672 937
Hydro (90th%)—Other 244 246 231 245 352 365 304 272 255 252 241 244
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 48 0 0 0 0 0
Total Hydro (90th%) 1,100 1,326 1,260 1,307 1,487 1,390 1,266 1,145 1,011 1,138 913 1,181
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
Clatskanie Exchange–Take 4 4 4 6 6 7 6 4 3 1 2 3
Clatskanie Exchange– Return 0 0 (10) (15) 0 0 0 0 0 (10) (15) 0
Total PPAs 29 40 30 27 42 43 41 40 39 27 23 39
Firm Pacific NW Import Capability 0 0 0 0 276 342 237 274 147 0 0 15
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,954 3,195 3,122 3,202 3,718 3,697 3,472 3,377 3,103 3,033 2,771 3,063
Monthly Surplus/Deficit 0 0 0 0 0 0 (24) 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 2 6 8 8 7 4 1 0 0
Commercial 19 19 19 19 19 20 20 20 19 19 19 19
Residential 1 1 1 1 1 1 1 1 1 1 1 1
Total New DSM Peak Reduction 20 20 20 21 26 28 29 27 23 20 20 20
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 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 443 801 1,034 1,243 846 381 5 299 270 988 501 364

Load and Resource Balance Data Idaho Power Company
Page 56 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,572) (2,452) (2,144) (2,013) (2,967) (3,401) (3,571) (3,163) (2,916) (2,109) (2,329) (2,764)
Existing DSM (EE) 26 26 26 27 29 30 30 29 28 26 26 26
Peak-Hour Forecast w/DSM (EE) (2,546) (2,426) (2,118) (1,986) (2,937) (3,371) (3,541) (3,134) (2,888) (2,083) (2,303) (2,738)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,546) (2,426) (2,118) (1,986) (2,937) (3,371) (3,541) (3,134) (2,888) (2,083) (2,303) (2,738)
Existing Resources
Coal 1,024 1,024 1,024 1,024 966 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 854 1,082 1,026 1,061 1,133 1,022 911 797 753 881 672 934
Hydro (90th%)—Other 244 248 231 244 353 365 303 233 256 252 241 244
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,098 1,329 1,257 1,305 1,485 1,388 1,215 1,030 1,009 1,133 913 1,178
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 0 0 0 0 314 342 237 272 178 0 0 34
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,948 3,194 3,125 3,209 3,692 3,688 3,415 3,256 3,129 3,037 2,784 3,076
Monthly Surplus/Deficit 0 0 0 0 0 0 (126) 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 2 7 9 10 8 4 1 0 0
Commercial 25 24 24 24 25 25 25 25 24 24 24 24
Residential 2 2 2 2 2 2 2 2 2 2 2 2
Total New DSM Peak Reduction 27 26 26 28 33 36 37 35 31 27 26 26
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (89) 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 0 0 0 0 0 100 100 100 0 0 0 0
New Resource Subtotal 0 0 0 0 0 100 100 100 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 429 794 1,034 1,251 788 452 11 258 272 981 508 364

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 57
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 (95th% w/no DSM) (2,603) (2,475) (2,169) (2,038) (3,016) (3,445) (3,632) (3,208) (2,961) (2,134) (2,358) (2,795)
Existing DSM (EE) 30 30 30 31 34 35 35 34 33 30 30 30
Peak-Hour Forecast w/DSM (EE) (2,574) (2,445) (2,139) (2,007) (2,982) (3,410) (3,596) (3,174) (2,929) (2,103) (2,328) (2,765)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,574) (2,445) (2,139) (2,007) (2,982) (3,410) (3,596) (3,174) (2,929) (2,103) (2,328) (2,765)
Existing Resources
Coal 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 852 1,080 1,023 1,060 1,132 1,020 909 794 750 875 673 932
Hydro (90th%)—Other 244 246 231 244 350 363 303 232 256 252 240 244
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,096 1,326 1,254 1,304 1,482 1,383 1,212 1,026 1,006 1,126 914 1,176
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 0 0 0 0 359 347 237 269 219 0 0 61
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,946 3,191 3,123 3,208 3,791 3,688 3,413 3,250 3,167 3,030 2,785 3,101
Monthly Surplus/Deficit 0 0 0 0 0 0 (184) 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 2 8 11 11 9 5 1 0 0
Commercial 29 29 29 29 30 30 30 30 29 29 29 30
Residential 4 4 4 4 4 3 3 3 4 4 4 4
Total New DSM Peak Reduction 33 33 33 35 41 44 45 43 38 34 33 33
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (139) 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 0 0 0 0 0 0 0 0 0 0 0 0
Demand Response 0 0 0 0 0 150 150 150 0 0 0 0
New Resource Subtotal 0 0 0 0 0 150 150 150 0 0 0 0
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 405 779 1,016 1,236 850 471 11 269 276 961 490 368

Load and Resource Balance Data Idaho Power Company
Page 58 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,629) (2,492) (2,190) (2,059) (3,064) (3,488) (3,691) (3,251) (3,003) (2,154) (2,381) (2,823)
Existing DSM (EE) 34 34 34 35 39 40 40 39 37 34 34 34
Peak-Hour Forecast w/DSM (EE) (2,595) (2,459) (2,156) (2,023) (3,025) (3,448) (3,651) (3,212) (2,966) (2,120) (2,347) (2,789)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,595) (2,459) (2,156) (2,023) (3,025) (3,448) (3,651) (3,212) (2,966) (2,120) (2,347) (2,789)
Existing Resources
Coal 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 850 1,073 1,013 1,058 1,131 1,017 907 790 747 870 673 930
Hydro (90th%)—Other 243 245 230 244 347 358 302 231 255 250 240 243
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 0 0 0 0 0 0
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,093 1,318 1,243 1,303 1,478 1,376 1,209 1,021 1,002 1,121 912 1,173
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 0 0 0 0 385 342 237 267 257 0 0 86
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,943 3,183 3,111 3,206 3,812 3,676 3,409 3,243 3,201 3,025 2,784 3,123
Monthly Surplus/Deficit 0 0 0 0 0 0 (242) 0 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 2 9 12 13 11 6 1 0 0
Commercial 35 35 35 35 35 36 36 36 35 35 35 35
Residential 7 7 7 7 7 6 6 6 7 7 7 7
Total New DSM Peak Reduction 42 42 41 44 51 55 55 53 48 42 42 42
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (187) 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 589 966 1,197 1,727 1,338 782 313 584 782 1,147 678 575

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 59
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 (95th% w/no DSM) (2,657) (2,511) (2,212) (2,081) (3,112) (3,532) (3,752) (3,295) (3,046) (2,176) (2,406) (2,851)
Existing DSM (EE) 37 37 37 39 44 45 45 44 41 38 37 37
Peak-Hour Forecast w/DSM (EE) (2,620) (2,474) (2,175) (2,042) (3,068) (3,487) (3,707) (3,251) (3,005) (2,139) (2,368) (2,814)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,620) (2,474) (2,175) (2,042) (3,068) (3,487) (3,707) (3,251) (3,005) (2,139) (2,368) (2,814)
Existing Resources
Coal 1,024 1,024 1,024 1,024 966 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 848 1,071 1,007 1,057 1,130 1,015 905 787 744 862 674 927
Hydro (90th%)—Other 243 245 230 243 344 355 302 231 229 250 238 242
Shoshone Falls Upgrade (90th%) 0 0 0 0 0 0 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,091 1,316 1,237 1,300 1,473 1,371 1,208 1,018 973 1,112 912 1,171
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 0 0 0 0 384 342 237 265 270 0 0 111
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,941 3,180 3,106 3,204 3,749 3,670 3,409 3,237 3,184 3,016 2,783 3,146
Monthly Surplus/Deficit 0 0 0 0 0 0 (298) (14) 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 3 10 14 15 12 7 1 0 0
Commercial 40 39 40 39 40 41 41 41 40 39 40 40
Residential 10 10 10 10 10 9 9 9 10 10 10 10
Total New DSM Peak Reduction 49 49 49 52 60 64 65 62 56 50 49 50
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (233) 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 570 956 1,180 1,713 1,241 747 267 548 736 1,128 664 582

Load and Resource Balance Data Idaho Power Company
Page 60 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,690) (2,535) (2,239) (2,107) (3,166) (3,580) (3,817) (3,342) (3,092) (2,204) (2,436) (2,885)
Existing DSM (EE) 42 42 42 44 49 50 51 49 46 43 42 42
Peak-Hour Forecast w/DSM (EE) (2,648) (2,493) (2,197) (2,063) (3,117) (3,529) (3,766) (3,293) (3,046) (2,161) (2,394) (2,843)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,648) (2,493) (2,197) (2,063) (3,117) (3,529) (3,766) (3,293) (3,046) (2,161) (2,394) (2,843)
Existing Resources
Coal 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024 1,024
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 843 1,068 1,005 1,056 1,128 1,013 902 783 741 853 673 927
Hydro (90th%)—Other 243 243 230 243 341 353 301 230 228 250 237 241
Shoshone Falls Upgrade (90th%) 3 2 0 0 9 11 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,088 1,313 1,235 1,298 1,479 1,377 1,205 1,013 968 1,103 910 1,170
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 0 0 0 0 383 342 237 262 269 0 4 139
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,938 3,178 3,104 3,202 3,811 3,676 3,406 3,230 3,179 3,007 2,785 3,173
Monthly Surplus/Deficit 0 0 0 0 0 0 (360) (64) 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 3 12 16 17 14 8 1 0 0
Commercial 45 45 45 45 46 47 47 47 45 45 46 45
Residential 9 9 9 9 9 8 8 8 9 9 9 9
Total New DSM Peak Reduction 54 54 54 57 66 71 72 69 62 55 55 54
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (288) 0 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 545 939 1,161 1,696 1,261 719 212 506 695 1,101 646 584

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 61
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 (95th% w/no DSM) (2,720) (2,564) (2,261) (2,126) (3,222) (3,627) (3,882) (3,391) (3,139) (2,232) (2,463) (2,919)
Existing DSM (EE) 45 45 45 48 54 55 56 54 51 46 45 45
Peak-Hour Forecast w/DSM (EE) (2,674) (2,519) (2,216) (2,079) (3,168) (3,572) (3,827) (3,337) (3,088) (2,186) (2,418) (2,874)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,674) (2,519) (2,216) (2,079) (3,168) (3,572) (3,827) (3,337) (3,088) (2,186) (2,418) (2,874)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 841 1,066 1,004 1,054 1,127 1,009 899 779 737 840 674 923
Hydro (90th%)—Other 242 243 229 243 341 328 300 229 227 248 235 241
Shoshone Falls Upgrade (90th%) 3 2 0 0 8 10 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,086 1,311 1,233 1,297 1,476 1,347 1,202 1,008 964 1,089 909 1,166
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 87 0 0 0 434 395 290 313 320 0 83 225
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,965 3,118 3,044 3,143 3,802 3,643 3,398 3,218 3,168 2,935 2,806 3,197
Monthly Surplus/Deficit 0 0 0 0 0 0 (429) (119) 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 4 13 19 20 16 9 2 0 0
Commercial 51 51 50 51 52 53 53 53 51 51 51 51
Residential 9 9 9 9 9 8 8 8 9 9 9 9
Total New DSM Peak Reduction 60 60 60 64 74 80 80 77 69 62 60 60
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (349) (41) 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 552 860 1,088 1,628 1,208 650 151 459 648 1,011 649 583

Load and Resource Balance Data Idaho Power Company
Page 62 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,745) (2,585) (2,281) (2,144) (3,272) (3,668) (3,941) (3,432) (3,180) (2,257) (2,487) (2,950)
Existing DSM (EE) 49 49 49 51 58 60 60 58 55 50 49 49
Peak-Hour Forecast w/DSM (EE) (2,696) (2,537) (2,232) (2,092) (3,213) (3,608) (3,881) (3,374) (3,126) (2,207) (2,438) (2,901)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,696) (2,537) (2,232) (2,092) (3,213) (3,608) (3,881) (3,374) (3,126) (2,207) (2,438) (2,901)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 839 1,063 1,000 1,052 1,126 1,006 896 775 733 831 674 920
Hydro (90th%)—Other 242 242 229 242 339 326 300 228 226 247 234 240
Shoshone Falls Upgrade (90th%) 3 2 0 0 8 9 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,083 1,307 1,229 1,294 1,473 1,342 1,198 1,003 960 1,078 909 1,162
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 113 0 0 0 433 349 237 308 318 0 103 254
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 2,988 3,115 3,040 3,140 3,798 3,591 3,341 3,208 3,162 2,924 2,826 3,222
Monthly Surplus/Deficit 0 0 0 0 0 (17) (540) (166) 0 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 4 15 22 22 19 10 2 0 0
Commercial 59 58 58 58 59 60 60 60 58 58 58 58
Residential 9 9 10 10 9 8 8 8 9 9 9 10
Total New DSM Peak Reduction 68 67 67 72 84 90 91 88 78 70 68 67
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (449) (78) 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 560 845 1,075 1,619 1,168 574 51 422 614 987 656 588

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 63
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 (95th% w/no DSM) (2,771) (2,603) (2,301) (2,164) (3,319) (3,709) (4,000) (3,474) (3,222) (2,278) (2,510) (2,976)
Existing DSM (EE) 52 52 52 55 62 64 65 62 58 53 52 52
Peak-Hour Forecast w/DSM (EE) (2,719) (2,551) (2,249) (2,109) (3,257) (3,645) (3,935) (3,412) (3,164) (2,225) (2,458) (2,924)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,719) (2,551) (2,249) (2,109) (3,257) (3,645) (3,935) (3,412) (3,164) (2,225) (2,458) (2,924)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 835 1,061 1,001 1,051 1,124 1,003 893 770 730 828 674 918
Hydro (90th%)—Other 241 242 228 241 336 323 299 227 225 246 234 240
Shoshone Falls Upgrade (90th%) 3 2 0 0 7 9 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,078 1,305 1,229 1,292 1,467 1,335 1,195 997 955 1,074 908 1,159
CSPP (PURPA) 86 89 93 128 174 181 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 136 0 0 0 431 346 237 306 316 0 123 291
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,007 3,112 3,040 3,138 3,790 3,580 3,337 3,201 3,156 2,921 2,845 3,257
Monthly Surplus/Deficit 0 0 0 0 0 (65) (598) (211) (9) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 5 18 25 26 22 11 2 0 0
Commercial 64 64 64 64 65 67 67 67 64 64 64 65
Residential 10 10 10 10 10 9 9 9 10 10 10 10
Total New DSM Peak Reduction 74 74 73 79 92 100 101 97 85 76 74 74
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (497) (114) 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 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 562 834 1,064 1,608 1,125 535 3 386 577 971 661 607

Load and Resource Balance Data Idaho Power Company
Page 64 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,783) (2,613) (2,308) (2,168) (3,363) (3,746) (4,055) (3,511) (3,259) (2,296) (2,522) (2,993)
Existing DSM (EE) 55 54 55 57 65 68 68 66 62 56 55 55
Peak-Hour Forecast w/DSM (EE) (2,728) (2,558) (2,254) (2,111) (3,298) (3,679) (3,987) (3,445) (3,198) (2,240) (2,467) (2,938)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,728) (2,558) (2,254) (2,111) (3,298) (3,679) (3,987) (3,445) (3,198) (2,240) (2,467) (2,938)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 832 1,058 999 1,049 1,112 1,000 891 766 727 819 673 917
Hydro (90th%)—Other 240 242 228 240 335 321 298 226 225 245 233 239
Shoshone Falls Upgrade (90th%) 3 2 0 0 7 9 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,075 1,301 1,228 1,289 1,453 1,330 1,191 992 951 1,064 906 1,158
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 143 0 0 0 430 342 237 303 315 0 132 312
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,011 3,109 3,039 3,135 3,775 3,572 3,334 3,192 3,150 2,911 2,852 3,276
Monthly Surplus/Deficit 0 0 0 0 0 (106) (653) (254) (47) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 6 20 28 29 25 13 2 0 0
Commercial 71 71 71 71 71 74 74 74 72 71 71 72
Residential 12 12 12 12 12 11 11 11 12 12 12 12
Total New DSM Peak Reduction 84 83 84 89 104 113 114 109 97 86 84 84
Remaining Monthly Surplus/Deficit 0 0 0 0 0 0 (539) (144) 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 50 50 50 0 0 0 0
New Resource Subtotal 200 200 200 500 500 550 550 550 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 567 834 1,068 1,614 1,081 557 11 406 550 956 669 623

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 65
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 (95th% w/no DSM) (2,786) (2,624) (2,308) (2,163) (3,406) (3,776) (4,105) (3,542) (3,291) (2,312) (2,527) (3,009)
Existing DSM (EE) 57 57 57 60 68 71 72 69 64 58 57 57
Peak-Hour Forecast w/DSM (EE) (2,730) (2,568) (2,252) (2,103) (3,337) (3,705) (4,033) (3,473) (3,226) (2,254) (2,470) (2,952)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,730) (2,568) (2,252) (2,103) (3,337) (3,705) (4,033) (3,473) (3,226) (2,254) (2,470) (2,952)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 830 1,055 998 1,047 1,111 998 888 761 723 812 674 914
Hydro (90th%)—Other 240 241 228 240 334 320 298 225 224 245 232 239
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,073 1,298 1,225 1,287 1,451 1,326 1,188 987 947 1,057 906 1,155
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 160 0 0 0 428 342 237 300 313 0 135 321
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,025 3,105 3,036 3,133 3,771 3,569 3,331 3,184 3,144 2,903 2,854 3,282
Monthly Surplus/Deficit 0 0 0 0 0 (137) (703) (289) (82) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 6 23 32 33 28 15 3 0 0
Commercial 77 77 77 77 77 80 80 80 77 77 78 77
Residential 16 16 16 16 16 14 14 14 16 16 16 16
Total New DSM Peak Reduction 93 93 93 99 116 126 127 122 108 96 94 93
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (10) (575) (167) 0 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 100 100 100 0 0 0 0
New Resource Subtotal 200 200 200 500 500 600 600 600 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 589 830 1,078 1,629 1,050 590 25 433 526 944 678 623

Load and Resource Balance Data Idaho Power Company
Page 66 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,810) (2,640) (2,326) (2,180) (3,450) (3,811) (4,157) (3,578) (3,328) (2,332) (2,548) (3,036)
Existing DSM (EE) 59 59 59 62 71 74 75 72 67 60 59 59
Peak-Hour Forecast w/DSM (EE) (2,751) (2,581) (2,267) (2,117) (3,379) (3,737) (4,083) (3,506) (3,262) (2,272) (2,489) (2,977)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,751) (2,581) (2,267) (2,117) (3,379) (3,737) (4,083) (3,506) (3,262) (2,272) (2,489) (2,977)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 827 1,050 994 1,046 1,109 995 885 758 720 803 675 910
Hydro (90th%)—Other 239 241 227 239 331 318 297 225 223 244 231 238
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,068 1,292 1,222 1,285 1,447 1,322 1,184 982 943 1,047 906 1,150
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 183 0 0 0 427 342 237 298 311 0 154 319
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,044 3,099 3,032 3,131 3,766 3,564 3,327 3,177 3,138 2,893 2,874 3,275
Monthly Surplus/Deficit 0 0 0 0 0 (173) (756) (329) (124) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 7 26 36 38 32 17 3 0 0
Commercial 83 83 83 83 84 86 86 86 83 83 84 83
Residential 21 21 21 21 21 18 18 18 21 21 21 21
Total New DSM Peak Reduction 104 104 104 111 131 141 142 136 120 107 105 104
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (32) (613) (193) (3) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 150 150 150 0 0 0 0
New Resource Subtotal 200 200 200 500 500 650 650 650 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 597 822 1,069 1,625 1,018 618 37 457 497 928 690 603

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 67
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 (95th% w/no DSM) (2,835) (2,657) (2,346) (2,199) (3,496) (3,854) (4,217) (3,622) (3,372) (2,354) (2,570) (3,061)
Existing DSM (EE) 61 61 61 64 74 77 77 74 69 63 61 61
Peak-Hour Forecast w/DSM (EE) (2,774) (2,596) (2,285) (2,135) (3,422) (3,777) (4,139) (3,547) (3,303) (2,291) (2,509) (3,000)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,774) (2,596) (2,285) (2,135) (3,422) (3,777) (4,139) (3,547) (3,303) (2,291) (2,509) (3,000)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825.0 1,047.9 990.6 1,044.4 1,107.9 992.1 882.4 753.7 716.2 795.7 675.6 891.3
Hydro (90th%)—Other 238.7 239.8 226.9 213.9 330.4 317.5 296.2 223.9 222.7 243.8 230.5 237.7
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 218 0 0 0 425 342 237 295 308 0 174 317
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,077 3,097 3,028 3,104 3,761 3,560 3,324 3,170 3,131 2,886 2,894 3,254
Monthly Surplus/Deficit 0 0 0 0 0 (217) (816) (378) (172) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 8 29 41 43 36 19 4 0 0
Commercial 89 88 88 88 90 92 92 92 89 89 89 89
Residential 27 27 27 27 26 23 23 23 27 27 27 27
Total New DSM Peak Reduction 116 115 115 123 146 156 158 151 134 119 115 115
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (61) (658) (226) (37) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 200 200 200 0 0 0 0
New Resource Subtotal 200 200 200 500 500 700 700 700 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 619 816 1,059 1,593 985 639 42 474 463 914 700 570

Load and Resource Balance Data Idaho Power Company
Page 68 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,844) (2,667) (2,350) (2,201) (3,538) (3,891) (4,270) (3,659) (3,408) (2,370) (2,579) (3,079)
Existing DSM (EE) 63 62 62 66 75 79 79 76 71 64 63 63
Peak-Hour Forecast w/DSM (EE) (2,781) (2,605) (2,288) (2,135) (3,463) (3,812) (4,191) (3,582) (3,337) (2,306) (2,517) (3,016)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,781) (2,605) (2,288) (2,135) (3,463) (3,812) (4,191) (3,582) (3,337) (2,306) (2,517) (3,016)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825.0 1047.9 990.6 1044.4 1107.9 992.1 882.4 753.7 716.2 795.7 675.6 891.3
Hydro (90th%)—Other 238.7 239.8 226.9 213.9 330.4 317.5 296.2 223.9 222.7 243.8 230.5 237.7
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 236 0 7 0 423 342 237 293 306 0 182 314
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,095 3,097 3,035 3,104 3,759 3,560 3,324 3,168 3,129 2,886 2,902 3,251
Monthly Surplus/Deficit 0 0 0 0 0 (252) (868) (414) (208) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 9 33 46 48 40 21 4 0 0
Commercial 96 94 94 95 96 98 98 98 95 95 95 96
Residential 33 33 33 33 33 29 29 29 33 33 33 33
Total New DSM Peak Reduction 128 127 127 137 161 174 175 168 149 132 128 128
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (78) (693) (247) (59) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 200 200 200 0 0 0 0
New Resource Subtotal 200 200 200 500 500 700 700 700 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 642 819 1,075 1,607 958 622 7 453 441 912 713 563

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 69
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 (95th% w/no DSM) (2,864) (2,680) (2,365) (2,214) (3,582) (3,927) (4,325) (3,697) (3,447) (2,389) (2,598) (3,104)
Existing DSM (EE) 64 64 64 68 77 80 81 78 73 65 64 64
Peak-Hour Forecast w/DSM (EE) (2,800) (2,616) (2,301) (2,147) (3,505) (3,847) (4,244) (3,619) (3,375) (2,324) (2,534) (3,040)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,800) (2,616) (2,301) (2,147) (3,505) (3,847) (4,244) (3,619) (3,375) (2,324) (2,534) (3,040)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825.0 1,047.9 990.6 1,044.4 1,107.9 992.1 882.4 753.7 716.2 795.7 675.6 891.3
Hydro (90th%)—Other 238.7 239.8 226.9 213.9 330.4 317.5 296.2 223.9 222.7 243.8 230.5 237.7
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 247 0 24 0 421 342 237 290 304 0 199 312
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,106 3,097 3,052 3,104 3,757 3,560 3,324 3,165 3,127 2,886 2,919 3,249
Monthly Surplus/Deficit 0 0 0 0 0 (287) (920) (454) (248) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 10 37 52 54 45 24 5 0 0
Commercial 100 100 100 100 101 104 104 104 101 100 100 101
Residential 38 38 38 38 37 33 33 33 37 38 38 37
Total New DSM Peak Reduction 138 138 137 148 175 189 191 182 163 142 138 139
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (98) (729) (271) (85) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 250 250 250 0 0 0 0
New Resource Subtotal 200 200 200 500 500 750 750 750 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 644 818 1,089 1,606 928 652 21 479 415 904 723 547

Load and Resource Balance Data Idaho Power Company
Page 70 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,902) (2,708) (2,395) (2,242) (3,635) (3,978) (4,391) (3,748) (3,498) (2,418) (2,631) (3,142)
Existing DSM (EE) 65 65 65 69 79 82 83 80 74 67 65 66
Peak-Hour Forecast w/DSM (EE) (2,836) (2,642) (2,329) (2,174) (3,556) (3,895) (4,308) (3,668) (3,424) (2,351) (2,566) (3,077)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,836) (2,642) (2,329) (2,174) (3,556) (3,895) (4,308) (3,668) (3,424) (2,351) (2,566) (3,077)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825 1,048 991 1,044 1,108 992 882 754 716 796 676 891
Hydro (90th%)—Other 239 240 227 214 330 317 296 224 223 244 230 238
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 281 0 61 0 419 342 237 287 302 0 231 310
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,140 3,097 3,089 3,104 3,755 3,560 3,324 3,162 3,125 2,886 2,951 3,247
Monthly Surplus/Deficit 0 0 0 0 0 (336) (984) (507) (299) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 11 38 54 56 47 25 5 0 0
Commercial 105 105 105 105 105 109 109 109 106 105 105 106
Residential 43 43 43 43 43 38 38 38 43 43 43 43
Total New DSM Peak Reduction 148 148 148 158 186 200 202 194 174 152 148 149
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (135) (782) (313) (125) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 300 300 300 0 0 0 0
New Resource Subtotal 200 200 200 500 500 800 800 800 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 652 802 1,108 1,589 886 665 18 487 375 887 733 519

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 71
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 (95th% w/no DSM) (2,918) (2,720) (2,405) (2,251) (3,679) (4,019) (4,448) (3,790) (3,540) (2,437) (2,646) (3,163)
Existing DSM (EE) 66 66 66 70 80 83 84 81 75 68 66 66
Peak-Hour Forecast w/DSM (EE) (2,851) (2,654) (2,339) (2,181) (3,599) (3,936) (4,365) (3,710) (3,465) (2,369) (2,580) (3,097)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,851) (2,654) (2,339) (2,181) (3,599) (3,936) (4,365) (3,710) (3,465) (2,369) (2,580) (3,097)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825 1,048 991 1,044 1,108 992 882 754 716 796 676 891
Hydro (90th%)—Other 239 240 227 214 330 317 296 224 223 244 230 238
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 291 12 78 15 418 342 237 285 300 0 245 308
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,150 3,109 3,106 3,119 3,754 3,560 3,324 3,160 3,123 2,886 2,965 3,245
Monthly Surplus/Deficit 0 0 0 0 0 (376) (1,041) (550) (342) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 11 40 56 58 49 26 5 0 0
Commercial 110 110 110 109 110 114 114 114 110 109 111 110
Residential 48 48 48 48 48 42 42 42 48 48 47 48
Total New DSM Peak Reduction 158 157 158 168 198 212 214 205 184 162 159 158
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (164) (827) (345) (158) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 350 350 350 0 0 0 0
New Resource Subtotal 200 200 200 500 500 850 850 850 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 656 812 1,125 1,606 853 686 23 505 342 879 743 505

Load and Resource Balance Data Idaho Power Company
Page 72 2013 Integrated Resource Plan—Appendix C
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 (95th% w/no DSM) (2,933) (2,719) (2,416) (2,260) (3,722) (4,057) (4,503) (3,829) (3,579) (2,455) (2,661) (3,185)
Existing DSM (EE) 67 67 67 70 81 84 84 81 75 68 67 67
Peak-Hour Forecast w/DSM (EE) (2,867) (2,652) (2,349) (2,189) (3,642) (3,973) (4,418) (3,748) (3,504) (2,387) (2,594) (3,118)
Existing DSM (DR) 0 0 0 0 0 0 0 0 0 0 0 0
Peak-Hour Forecast w/DSM (DR) (2,867) (2,652) (2,349) (2,189) (3,642) (3,973) (4,418) (3,748) (3,504) (2,387) (2,594) (3,118)
Existing Resources
Coal 966 966 966 966 966 966 966 966 966 966 966 966
Gas (Langley Gulch) 300 300 300 300 300 300 300 300 300 300 300 300
Hydro (90th%)—HCC 825 1,048 991 1,044 1,108 992 882 754 716 796 676 891
Hydro (90th%)—Other 239 240 227 214 330 317 296 224 223 244 230 238
Shoshone Falls Upgrade (90th%) 3 2 0 0 6 8 2 0 0 0 0 2
Sho-Ban Water Lease 0 0 0 0 0 0 0 0 0 0 0 0
Total Hydro (90th%) 1,066 1,289 1,218 1,258 1,444 1,318 1,181 978 939 1,040 906 1,131
CSPP (PURPA) 86 89 93 128 174 182 189 179 167 128 96 88
PPAs
Elkhorn Valley Wind 5 5 5 5 5 5 5 5 5 5 5 5
Raft River Geothermal 9 9 9 9 9 9 9 9 9 9 9 9
Neal Hot Springs Geothermal 11 22 22 22 22 22 21 22 22 22 22 22
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 25 36 36 36 36 36 35 36 36 36 36 36
Firm Pacific NW Import Capability 313 10 85 33 416 342 237 281 299 0 259 306
Gas Peakers 416 416 416 416 416 416 416 416 416 416 416 416
Existing Resource Subtotal 3,172 3,107 3,113 3,137 3,752 3,560 3,324 3,156 3,122 2,886 2,979 3,243
Monthly Surplus/Deficit 0 0 0 0 0 (413) (1,095) (592) (382) 0 0 0
2013 IRP DSM (EE)
Irrigation 0 0 0 12 42 59 61 51 27 5 0 0
Commercial 115 115 114 114 117 119 119 119 115 115 115 115
Residential 52 52 52 52 52 46 46 46 52 52 52 52
Total New DSM Peak Reduction 167 167 167 178 210 224 226 216 194 172 167 167
Remaining Monthly Surplus/Deficit 0 0 0 0 0 (190) (869) (375) (187) 0 0 0
2013 IRP Resources
2018 Boardman to Hemingway 200 200 200 500 500 500 500 500 500 200 200 200
Demand Response 0 0 0 0 0 370 370 370 0 0 0 0
New Resource Subtotal 200 200 200 500 500 870 870 870 500 200 200 200
Monthly Surplus/Deficit 0 0 0 0 0 0 0 0 0 0 0 0
Remaining Monthly Surplus/Deficit 672 821 1,131 1,627 821 680 1 495 313 871 752 492

Idaho Power Company Load and Resource Balance Data
2013 Integrated Resource Plan—Appendix C Page 73
Peak-Hour Surplus/Deficit Charts
Peak-hour monthly deficits with existing DSM and existing resources

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

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

(1,400)
(1,200)
(1,000)
(800)
(600)
(400)
(200)
0
1/2
0
1
3
1/2
0
1
4
1/2
0
1
5
1/2
0
1
6
1/2
0
1
7
1/2
0
1
8
1/2
0
1
9
1/2
0
2
0
1/2
0
2
1
1/2
0
2
2
1/2
0
2
3
1/2
0
2
4
1/2
0
2
5
1/2
0
2
6
1/2
0
2
7
1/2
0
2
8
1/2
0
2
9
1/2
0
3
0
1/2
0
3
1
1/2
0
3
2
aM
W
(1,400)
(1,200)
(1,000)
(800)
(600)
(400)
(200)
0
1/
2
0
1
3
1/
2
0
1
4
1/
2
0
1
5
1/
2
0
1
6
1/
2
0
1
7
1/
2
0
1
8
1/
2
0
1
9
1/
2
0
2
0
1/
2
0
2
1
1/
2
0
2
2
1/
2
0
2
3
1/
2
0
2
4
1/
2
0
2
5
1/
2
0
2
6
1/
2
0
2
7
1/
2
0
2
8
1/
2
0
2
9
1/
2
0
3
0
1/
2
0
3
1
1/
2
0
3
2
aM
W
(1,000)
(900)
(800)
(700)
(600)
(500)
(400)
(300)
(200)
(100)
0
1/
2
0
1
3
1/
2
0
1
4
1/
2
0
1
5
1/
2
0
1
6
1/
2
0
1
7
1/
2
0
1
8
1/
2
0
1
9
1/
2
0
2
0
1/
2
0
2
1
1/
2
0
2
2
1/
2
0
2
3
1/
2
0
2
4
1/
2
0
2
5
1/
2
0
2
6
1/
2
0
2
7
1/
2
0
2
8
1/
2
0
2
9
1/
2
0
3
0
1/
2
0
3
1
1/
2
0
3
2
MW
Demand-Side Resource Data Idaho Power Company
Page 74 2013 Integrated Resource Plan—Appendix C
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, (http://www.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.
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) 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.
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
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.
Idaho Power may choose to launch a pilot or limited-scale program 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,
Idaho Power Company Demand-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 75
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 will verify
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.
The financial assumptions used in the analysis for the 2013 IRP are consistent with the financial
assumptions made for supply-side resources, including the discount rate and cost escalation rates. 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).
Alternate Costs
The prices of avoided energy throughout the 20-year planning period were simulated using the Preferred
Portfolio module within the AURORA model. The preferred portfolio module considers the energy
capacity and resource costs of the current preferred mix of IRP resources along with regional
transmission resources in the Western Electricity Coordinating Council (WECC) region to project
forward marginal electricity prices. The forward prices are placed into five homogenous pricing categories that follow the pattern of heavy- and light-load pricing throughout each year of the planning
period. The resulting categories are:
• 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. The estimated levelized capacity
cost of a new SCCT is approximately $102 per kW over a 30-year period. When multiplied by the
Effective Load Carry Capacity (ELCC) of 93 percent, the annual avoided capacity cost is $95/kW.
For demand response or direct load control DSM programs $95 per kW becomes the cost threshold for program cost-effectiveness. 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 depending on the calendar year.
Demand-Side Resource Data Idaho Power Company
Page 76 2013 Integrated Resource Plan—Appendix C
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 3 percent annually beyond the planning period.
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 show the 20-year cumulative forecasted impact of energy efficiency by
customer class, and the associated annual TRC.
Table DSM-7 outlines the 20-year flow of avoided generation and the benefits attributed to energy
efficiency programs.
Table DSM-8 summarizes the cost-effectiveness analysis for energy efficiency programs through the 20-year IRP planning period.
Table DSM-9 summarizes the 20 year cumulative forecasted new potential for energy efficiency.
Table DSM-1. IRP financial assumptions
DSM Analysis Assumptions
Avoided 30-Year Levelized Capacity Costs
SCCT ......................................................................................................................................................................... $102/kW
Financial Assumptions
Weighted average cost of capital (2008 year ending after tax) .................................................................................. 6.77%
Financial escalation factor ......................................................................................................................................... 3.00%
Transmission Losses
Non-summer secondary losses ................................................................................................................................. 10.90%
Summer peak loss ..................................................................................................................................................... 13.00%

Idaho Power Company Demand-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 77
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)
2013 $76.49 $34.48 $25.31 $34.93 $30.02
2014 $80.75 $37.08 $27.11 $37.34 $31.76
2015 $84.72 $39.35 $29.10 $40.13 $33.67
2016 $86.92 $40.96 $30.40 $41.62 $34.89
2017 $89.91 $43.92 $31.84 $43.66 $36.65
2018 $105.15 $56.81 $41.02 $56.36 $48.35
2019 $110.73 $59.75 $43.63 $58.59 $50.43
2020 $116.20 $63.46 $46.03 $60.93 $52.05
2021 $123.89 $68.11 $49.29 $65.65 $55.83
2022 $133.18 $73.43 $53.52 $71.81 $60.51
2023 $141.12 $76.86 $57.74 $76.07 $64.49
2024 $148.17 $83.42 $60.91 $80.83 $68.21
2025 $156.30 $87.00 $65.11 $86.57 $72.62
2026 $163.99 $91.41 $68.20 $92.53 $77.24
2027 $172.62 $96.14 $72.06 $97.31 $80.92
2028 $180.43 $102.13 $75.83 $103.04 $85.24
2029 $188.75 $107.61 $78.85 $106.65 $89.01
2030 $197.88 $116.12 $82.84 $112.22 $94.27
2031 $207.57 $121.61 $86.58 $118.59 $98.88
2032 $218.39 $133.14 $91.20 $125.54 $104.29
* Estimated variable operations and management costs of a 170 MW capacity SCCT.

Demand-Side Resource Data Idaho Power Company
Page 78 2013 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
2013 Integrated Resource Plan—Appendix C Page 79
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 80 2013 Integrated Resource Plan—Appendix C
Table DSM-5. Cumulative existing energy efficiency portfolio forecast 2013–2032 (aMW w/transmission losses)
Year Commercial/Industrial Irrigation Residential Total
2013 ...................................... 11 3 1 15
2014 ...................................... 20 7 3 30
2015 ...................................... 29 11 4 44
2016 ...................................... 37 14 5 56
2017 ...................................... 45 18 6 69
2018 ...................................... 53 22 7 82
2019 ...................................... 60 26 8 94
2020 ...................................... 68 27 10 105
2021 ...................................... 76 29 11 116
2022 ...................................... 86 30 13 129
2023 ...................................... 94 31 14 139
2024 ...................................... 103 35 16 154
2025 ...................................... 111 39 18 168
2026 ...................................... 118 44 19 181
2027 ...................................... 125 50 21 196
2028 ...................................... 133 57 23 213
2029 ...................................... 139 61 26 226
2030 ...................................... 145 67 27 239
2031 ...................................... 151 72 27 250
2032 ...................................... 157 76 28 261

Table DSM-6. Existing energy efficiency portfolio TRC 2013–2032
Year Commercial/Industrial Irrigation Residential Total All Sectors
2013 ...................................... $17,684,888 $4,444,305 $5,086,693 $18,384,322
2014 ...................................... $15,023,476 $4,457,135 $5,234,296 $19,369,878
2015 ...................................... $14,489,836 $5,436,652 $4,658,449 $21,075,362
2016 ...................................... $15,795,923 $5,422,132 $3,079,095 $24,297,150
2017 ...................................... $12,804,433 $6,222,769 $3,485,460 $22,512,662
2018 ...................................... $18,933,992 $8,491,051 $3,832,902 $31,257,946
2019 ...................................... $14,504,997 $8,473,738 $4,116,430 $27,095,166
2020 ...................................... $16,784,968 $11,988,119 $4,458,449 $33,231,536
2021 ...................................... $16,569,043 $15,941,955 $4,777,871 $37,288,869
2022 ...................................... $24,300,214 $12,054,486 $5,258,756 $41,613,456
2023 ...................................... $21,616,897 $11,248,712 $5,519,440 $38,385,049
2024 ...................................... $24,308,004 $22,807,017 $5,908,096 $53,023,117
2025 ...................................... $19,146,569 $27,109,620 $6,319,791 $52,575,980
2026 ...................................... $17,637,971 $18,967,276 $6,673,290 $43,278,537
2027 ...................................... $16,436,862 $18,996,353 $7,018,133 $42,451,348
2028 ...................................... $20,547,973 $19,800,123 $7,405,932 $47,754,028
2029 ...................................... $18,360,242 $17,039,341 $7,748,039 $43,147,622
2030 ...................................... $16,662,697 $19,003,939 $3,224,961 $38,891,596
2031 ...................................... $15,856,083 $17,560,593 $3,375,416 $36,792,091
2032 ...................................... $20,858,372 $12,799,825 $3,245,360 $36,903,556
20-Year NPV ......................... $188,245,928 $123,502,451 $52,623,496 $364,755,770
Idaho Power Company Demand-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 81
Table DSM-7. Existing energy efficiency portfolio avoided energy costs 2013–2032
Year Commercial/Industrial Irrigation Residential Total All Sectors
2013 ...................................... $1,995,192 $785,140 $82,481 $2,862,813
2014 ...................................... $4,447,169 $1,877,276 $306,505 $6,630,950
2015 ...................................... $7,448,806 $3,562,786 $608,946 $11,620,538
2016 ...................................... $10,536,474 $4,823,818 $936,699 $16,296,990
2017 ...................................... $13,603,373 $6,184,262 $1,326,187 $21,113,822
2018 ...................................... $21,636,893 $10,091,290 $2,252,452 $33,980,635
2019 ...................................... $26,150,714 $12,719,356 $2,941,227 $41,811,296
2020 ...................................... $31,747,645 $13,994,828 $3,744,939 $49,487,412
2021 ...................................... $37,762,710 $15,493,623 $4,672,567 $57,928,901
2022 ...................................... $45,798,427 $17,142,980 $5,825,460 $68,766,868
2023 ...................................... $52,827,025 $18,655,035 $7,029,285 $78,511,345
2024 ...................................... $60,135,516 $21,307,128 $8,281,800 $89,724,444
2025 ...................................... $67,330,305 $24,745,002 $9,733,405 $101,808,713
2026 ...................................... $75,445,701 $29,484,780 $11,436,383 $116,366,864
2027 ...................................... $83,498,887 $34,951,122 $13,269,044 $131,719,053
2028 ...................................... $93,058,554 $41,361,986 $15,432,666 $149,853,206
2029 ...................................... $101,824,572 $46,837,103 $17,697,063 $166,358,738
2030 ...................................... $112,112,296 $53,607,202 $19,343,108 $185,062,606
2031 ...................................... $120,032,498 $59,203,492 $20,675,610 $199,911,600
2032 ...................................... $128,401,187 $64,820,001 $22,038,852 $215,260,039
20-Year NPV ......................... $437,466,195 $189,233,708 $63,693,931 $690,393,833

Table DSM-8. Existing energy efficiency portfolio cost-effectiveness summary
Impact 20-Year NPV TRC
2032 Load (aMW) Resource Costs Alternate Energy Benefits B/C Ratio Levelized Costs ($/kWh)
Industrial/Commercial .. 157 $188,245,928 $467,521,430 2.5 0.028
Residential .................. 76 $123,886,346 $190,935,664 1.5 0.046
Irrigation ...................... 28 $52,623,496 $76,220,052 1.4 0.049
Total ........................... 261 $364,755,770 $734,677,146 2.0 0.035

Demand-Side Resource Data Idaho Power Company
Page 82 2013 Integrated Resource Plan—Appendix C
Table DSM-9. Cumulative new energy efficiency portfolio forecast 2013–2032 (aMW w/transmission losses)
Year
Commercial/
Industrial Residential Irrigation Total
2013 .................................................................................................. 6 0 1 8
2014 .................................................................................................. 13 0 2 15
2015 .................................................................................................. 19 1 3 23
2016 .................................................................................................. 25 2 3 30
2017 .................................................................................................. 30 4 4 37
2018 .................................................................................................. 35 6 5 46
2019 .................................................................................................. 40 10 5 55
2020 .................................................................................................. 46 9 6 60
2021 .................................................................................................. 51 9 7 67
2022 .................................................................................................. 59 9 8 76
2023 .................................................................................................. 65 9 9 83
2024 .................................................................................................. 72 12 10 94
2025 .................................................................................................. 78 16 12 105
2026 .................................................................................................. 84 20 13 117
2027 .................................................................................................. 90 26 15 130
2028 .................................................................................................. 96 32 17 145
2029 .................................................................................................. 101 36 19 157
2030 .................................................................................................. 106 41 20 167
2031 .................................................................................................. 111 46 21 178
2032 .................................................................................................. 116 51 21 188

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 83
SUPPLY-SIDE RESOURCE DATA
Key Financial and Forecast Assumptions
Financing Cap Structure and Cost
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 ............................................................................................................................................... 30 Years
Discount rate (weighted average cost of capital1) ........................................................................................................... 6.70%
Composite tax rate .......................................................................................................................................................... 39.10%
Deferred rate ................................................................................................................................................................... 35.00%
General O&M escalation rate .......................................................................................................................................... 3.00%
Emissions adder escalation rate ..................................................................................................................................... 3.00%
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) ....................................................................................................................................................... 7.78%
1 Incorporates tax effects.

Emission Intensity Rate (lbs per MWh by technology, adder brought into the analysis beginning in 2018)
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 2013 Integrated Resource Plan—Appendix C
Emissions Adder Rates
CO2 ...................................................................................................................................................... $14.64 per ton (2018 $)

Fuel Forecast Base Case (Nominal, $ per MMBtu)
Year Natural Gas1 Regional Coal Uranium2
2013 ........................................................................................................... $5.55 $2.32 $0.70
2014 ........................................................................................................... $5.88 $2.44 $0.70
2015 ........................................................................................................... $6.19 $2.42 $0.71
2016 ........................................................................................................... $6.35 $2.45 $0.71
2017 ........................................................................................................... $6.57 $2.56 $0.72
2018 ........................................................................................................... $6.83 $2.68 $0.72
2019 ........................................................................................................... $7.22 $2.64 $0.73
2020 ........................................................................................................... $7.59 $2.70 $0.73
2021 ........................................................................................................... $8.15 $2.79 $0.73
2022 ........................................................................................................... $8.84 $2.89 $0.74
2023 ........................................................................................................... $9.42 $2.98 $0.74
2024 ........................................................................................................... $9.91 $3.07 $0.75
2025 ........................................................................................................... $10.49 $3.17 $0.75
2026 ........................................................................................................... $11.03 $3.27 $0.76
2027 ........................................................................................................... $11.65 $3.38 $0.76
2028 ........................................................................................................... $12.19 $3.48 $0.77
2029 ........................................................................................................... $12.76 $3.59 $0.77
2030 ........................................................................................................... $13.40 $3.71 $0.77
2031 ........................................................................................................... $14.09 $3.87 $0.78
2032 ........................................................................................................... $14.86 $4.00 $0.78
2033 ........................................................................................................... $14.95 $4.02 $0.79
2034 ........................................................................................................... $15.04 $4.04 $0.79
2035 ........................................................................................................... $15.13 $4.07 $0.80
2036 ........................................................................................................... $15.22 $4.09 $0.80
2037 ........................................................................................................... $15.31 $4.12 $0.81
2038 ........................................................................................................... $15.40 $4.14 $0.81
2039 ........................................................................................................... $15.49 $4.17 $0.82
2040 ........................................................................................................... $15.59 $4.19 $0.82
2041 ........................................................................................................... $15.68 $4.22 $0.83
2042 ........................................................................................................... $15.78 $4.24 $0.83
1 Henry Hub + Sumas basis + transportation cost = Idaho city gate price
2 Nuclear fuel

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 85
Cost Inputs and Operating Assumptions
(All costs in 2013 dollars)
Supply-Side Resources
Plant Capacity (MW)
Plant Capital ($/kW)1,3 Transmission Capital $/kW
Total Capital $/kW
Total Investment $/kW2
Fixed O&M $/kW3
Variable O&M $/kW Emissions $/MWh
Heat Rate Btu/kWh
Advanced Nuclear 250 $6,866 $625 $7,491 $11,381 $143 $1 $0 10,488
Biomass Digesters 50 $4,311 $285 $4,596 $4,921 $107 $16 $0 NA
CCCT—(1x1) F Class 270 $1,120 $140 $1,260 $1,477 $8 $2 $7 6,800
CCCT—(2x1) F Class 580 $1,039 $109 $1,148 $1,346 $6 $2 $7 6,738
CHP/Co-Generation 100 $1,975 $25 $2,000 $2,142 $8 $5 $0 9,200
Conventional Scrubbed Coal 600 $3,253 $730 $3,983 $4,754 $26 $4 $26 9,200
Distributed Generation (Option # 1) Load shed 10 $0 $0 $0 $0 $63 $0 $0 9,050
Distributed Generation (Option # 2) Grid synchronized 15 $0 $160 $160 $166 $63 $0 $0 9,050
Geothermal—Idaho 26 $6,630 $979 $7,609 $8,442 $144 $5 $0 NA
Geothermal—Nevada 26 $6,630 $552 $7,182 $7,968 $144 $5 $0 NA
Geothermal—Oregon 26 $6,630 $787 $7,417 $8,229 $144 $5 $0 NA
IGCC 550 $4,513 $730 $5,243 $6,547 $35 $7 $25 8,765
Low Drop/Small Hydro New 10 $4,000 $80 $4,080 $4,784 $15 $4 $0 NA
Pulverized Coal w/ carbon capture and sequestration 455 $7,755 $730 $8,485 $10,595 $143 $7 $5 12,600
Pumped Storage Fueled by LL Wind 500 $2,510 $646 $3,156 $3,700 $5 $0 $0 NA
SCCT—Industrial Frame 170 $733 $88 $821 $875 $4 $3 $13 11,870
SCCT—Large Aeroderivative 100 $1,250 $149 $1,399 $1,491 $15 $3 $10 8,800
SCCT—Small Aeroderivative 47 $1,113 $31 $1,144 $1,219 $14 $5 $8 9,370
Solar—1-Axis Tracking Flat Plate PV (Utility) 1 $4,029 $0 $4,029 $4,108 $27 $0 $0 NA
Solar—1-Axis Tracking Flat Plate PV (Utility 10 MW) 10 $3,268 $80 $3,348 $3,414 $27 $0 $0 NA
Solar—Concentrating Solar Power 100 $5,398 $212 $5,610 $6,578 $56 $0 $0 NA
Solar—Concentrating Solar Power with Energy Storage 100 $7,771 $212 $7,983 $9,360 $56 $0 $0 NA
Solar—Flat Plate PV (Distributed)4 10 $5,610 $0 $5,610 $5,720 $55 $0 $0 NA
Solar—Flat Plate PV (Utility) 1 $3,714 $0 $3,714 $3,787 $27 $0 $0 NA
Solar—Flat Plate PV (Utility 10MW) 10 $2,996 $80 $3,076 $3,136 $27 $0 $0 NA
Transmission—Boardman to Hemingway5 350 $0 $602 $602 $602 $1 $0 $0 NA
Wind—Eastern Oregon 100 $2,229 $1,210 $3,439 $3,675 $37 $1 $0 NA
Wind—Magic Valley 100 $2,229 $369 $2,598 $2,776 $37 $1 $0 NA
Wind—Southeast Idaho 100 $2,229 $382 $2,611 $2,790 $37 $1 $0 NA
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)
4 Approximately 2,500 4-kW PV systems.
5 350-MW average, 500-MW summer, and 200-MW winter.

Supply-Side Resource Data Idaho Power Company
Page 86 2013 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
Advanced Nuclear
250 $625 Pro-rated the 250 MW based on Idaho Power’s present 21.2% share of estimated $900 million Boardman to Hemingway project cost plus BPA wheeling rates to get to Boardman Station
230 kV upgrades from Hemingway to Bowmont and Hubbard stations Assume transmission in place by 2025 for access to Boardman area from Central Washington. Use BPA tariff rate to Boardman and pro-rata share of Boardman to Hemingway to Treasure Valley.
Biomass Digesters
50 $285 Assume multiple feeder locations. Assume $250 thousand of feeder upgrades per 10 MW plus 138-kV integration costs. Assume Jerome area integration requiring 138-kV transformer, breaker and miscellaneous line work and station reconfigurations.
Assume multiple feeder locations. Assume $250 thousand of feeder upgrades per 10 MW plus 138-kV integration costs. Assume Jerome area integration requiring 138-kV transformer, breaker, and miscellaneous line work and station reconfigurations.
Assume pro-rata share of Midpoint West path upgrades.
CCCT—(1x1) F Class
270 $140 Build new facility between Mountain Home and Boise with associated 230-kV plan of service
consisting of 230-kV switching station with a 22-mile, 230-kV line to Boise Bench substation and double circuit in/out of existing 230-kV line.
New supporting transmission will be required. Entire project assumed as backbone upgrade.
Build new facility between Mountain Home and Boise with associated 230-kV plan of service
consisting of 230-kV switching station with a 22-mile, 230-kV line to Boise Bench substation and double circuit in/out of existing 230-kV line.
CCCT—(2x1) F Class
580 $109 Build new facility between Mountain Home and Boise with associated 230-kV plan of service consisting of 230-kV switching station a 22-mile, 230-kV line to Boise Bench substation and a new 28-mile, 230-kV line to Hubbard substation.
New supporting transmission will be required. Entire project assumed as backbone upgrade.
Build new facility between Mountain Home and Boise with associated 230-kV plan of service consisting of 230-kV switching station a 22-mile, 230-kV line to Boise Bench substation and a new 28-mile, 230-kV line to Hubbard substation.
CHP/Co-Generation
100 $25 Assume Amalgamated Sugar location. Interconnection requires a tap of existing 138-kV line. Interconnection will require approximately 0.5 mile, 138-kV line and tap substation.
Approximately 0.5 mile, 138-kV line and 138-kV source substation with transformer.
Assume no additional transmission required.
Conventional Scrubbed Coal
600 $730 Assume Wyoming location requiring pro-rata share of 3000 MW Gateway West project.
Assume transmission in place to access Aeolus from resource location. Use tariff rate for capacity to Aeolus and then pro-rata share of Gateway West to Treasure Valley.
Pro-rata share of Gateway.
Distributed Generation—(Option # 1) Load Shed
10 $0 No upgrades required for load shed. No upgrades required for load shed. No backbone upgrades required.
Distributed Generation—(Option # 2) Grid synchronized
15 $160 Assume feeder interconnection with minor amount of distribution rebuild.
Assume a small amount of distribution rebuild. No backbone upgrades required.
Geothermal—Idaho
26 $979 Assume Raft River area geothermal with 45 mile, 138-kV line to Minidoka area substation
with new 138-line bay. Assume 26 MW fits on existing backbone.
Assume Raft River area geothermal with 45 mile, 138-kV line to Minidoka area substation with new 138-line bay.
No backbone upgrades required.

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 87
Capacity (MW Rating)
Overnight Transmission Capital Cost/kW1 Cost Assumptions Notes Local Interconnection Assumptions Backbone Transmission Assumptions
Geothermal—Nevada
26 $552 Assume a location 20 miles from existing 138-kV line. Assume 26 MW fits on existing 138-kV line.
Assume 20 miles of 138-kV local transmission to point of interconnection at 138-kV substation.
No backbone upgrades required.
Geothermal—Oregon
26 $787 Assume a project similar to Neal Hot Springs Interconnect (1 breaker station, line switches,
10-mile interconnect). Assume 26 MW fits on existing backbone.
Assume 10 miles of 138-kV local transmission to point of interconnection at 138-kV substation.
No backbone upgrades required.
IGCC
550 $730 Assume Wyoming location requiring pro-rata share of 3000 MW Gateway West project.
Assume transmission in place to access Aeolus from resource location. Use tariff rate for capacity to Aeolus and then pro-rata share of Gateway West to Treasure Valley.
Pro-rata share of Gateway.
Low Drop/Small Hydro New
10 $80 Assume 46-kV sub-transmission or local feeder interconnection. Assume 4 miles of distribution rebuild required.
Assume 4 miles of distribution rebuild required. No backbone upgrades required.
Pumped Storage Fueled by LL Wind
500 $646 Assume multiple locations. Assume 20-mile, 138- or 230-kV interconnection per location.
Assume multiple locations. Assume 20-mile, 138- or 230-kV interconnection per location.
No backbone upgrades assumed in the upgrade costs; however, this assumption will vary drastically based on size of resource and number of locations
Pulverized Coal with Carbon Capture and Sequestration
455 $730 Assume Wyoming location
requiring pro-rata share of 3000 MW Gateway West project.
Assume transmission in place to
access Aeolus from resource location. Use tariff rate for capacity to Aeolus and then pro-rata share of Gateway West to Treasure Valley.
Pro-rata share of Gateway.
SCCT—Industrial Frame
170 $88 See requirements in previous estimate and also rebuild 16 miles of existing 230-kV construction to bundled conductor.
Langley Substation expansion, new transformer terminal. 9 miles of new urban 230-kV transmission plus three-terminal expansion of existing Caldwell-area substation, 16 mile, 230-kV bundled conductor rebuild of Caldwell–Langley line.
SCCT—Large Aeroderivative
100 $149 9 miles of new urban 230-kV transmission plus three-terminal expansion of existing Caldwell-area substation plus Langley site expansion for second
generating unit (new transformer terminal in substation).
Langley substation expansion, new transformer terminal. 9 miles of new urban 230-kV transmission plus three-terminal expansion of existing Caldwell-area substation
SCCT—Small Aeroderivative
47 $31 Assume an addition to existing generation site in Mountain Home area. New 230-kV terminal and associated station modifications.
New 230-kV terminal and associated station modifications. No backbone upgrades required.
Solar—1-Axis Tracking Flat Plate PV (Utility 10 MW)
10 $80 Assume 34.5 kV feeder interconnection. Assume 4 miles of distribution rebuild required.
Assume 4 miles of distribution rebuild required. No backbone upgrades required.
Solar—1-Axis Tracking Flat Plate PV (Utility)
1 $0 12.5-kV feeder interconnection. No upgrades required. 12.5-kV feeder interconnection. No upgrades required. No backbone upgrades required.
Solar—Flat Plate PV (Distributed)2
10 $0 12.5-kV feeder interconnection. No upgrades required. 12.5-kV feeder interconnection. No upgrades required. No backbone upgrades required.
Supply-Side Resource Data Idaho Power Company
Page 88 2013 Integrated Resource Plan—Appendix C

Capacity (MW Rating)
Overnight Transmission Capital Cost/kW1 Cost Assumptions Notes Local Interconnection Assumptions Backbone Transmission Assumptions
Solar—Flat Plate PV (Utility 10 MW)
10 $80 Assume 34.5-kV feeder interconnection. Assume 4 miles of distribution rebuild required.
Assume 4 miles of distribution rebuild required. No backbone upgrades required.
Solar—Flat Plate PV (Utility)
1 $0 12.5-kV feeder interconnection. No upgrades required. 12.5-kV feeder interconnection. No upgrades required. No backbone upgrades required.
Solar—Concentrating Solar Power
100 $212 Assume Mountain Home desert area with 15 mile, 138-kV line (or multiple 34.5-kV feeders) to new substation intersecting existing 230-kV line.
Assume Mountain Home desert area with 15 mile, 138-kV line (or multiple 34.5-kV feeders) to new substation intersecting existing 230-kV line. Assume multi-transformer station.
New three-terminal 230-kV switching station connecting existing 230-kV line.
Solar—Concentrating Solar Power with Energy Storage
100 $212 Assume Mountain Home desert area with 15 mile, 138-kV line (or multiple 34.5-kV feeders) to new substation intersecting existing 230-kV line.
Assume Mountain Home desert area with 15 mile, 138-kV line (or multiple 34.5-kV feeders) to new substation intersecting existing 230-kV line. Assume multi-transformer station.
New three-terminal 230-kV switching station connecting existing 230-kV line.
Transmission—Boardman to Hemingway
350–Average 500–Summer 200–Winter
$602 Per the Boardman to Hemingway Funding Agreement, Idaho Power’s share of the project is 21.2% of an estimated $900 million project cost. Project also requires 230-kV local interconnection upgrades from Hemingway into the Treasure Valley.
230-kV upgrades from Hemingway to Bowmont and Hubbard Pro-rata share of Boardman to Hemingway.
Wind—Eastern Oregon
100 $1,210 Assume location near Quartz Substation. A new 110 mile, 230-kV line will need to be constructed into Treasure Valley.
Assume 10 miles of 138-kV local transmission to point of interconnection at 138-kV substation.
110 mile, 230-kV line to Treasure Valley.
Wind—Magic Valley
100 $369 Assume 10 mile interconnection to existing 230/138-kV substation plus 230-kV substation upgrades plus 1/16th share of Gateway West segment between Cedar Hill and Hemingway
Assume 10 miles of 138-kV local transmission to point of interconnection at 138-kV substation.
Upgrades at 230/138 kV integration substation + 100 MW pro-rata share of 1600-MW Cedar Hill–Hemingway 500-kV line
Wind—Southeast Idaho
100 $382 Assume 10 mile interconnection to local 138-kV substation plus Borah West path RAS upgrades plus 1/16th share of Gateway West segment between Cedar Hill and Hemingway
Assume 138-kV step-up station with transformer with 10 miles of 138-kV local transmission to 138-kV point of interconnection.
New terminal at 138-kV point of interconnection plus Borah West RAS upgrades plus 100 MW pro-rata share of 1600-MW Cedar Hill–Hemingway 500-kV line
1 2013 dollars, no AFUDC
2 Approximately 2,500 4-kW PV systems.

Idaho Power Company Supply-Side Resource Data
2013 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 Emission Adders
Total Cost per MWh1
Annual Capacity Factor
Advanced Nuclear (250 MW) $156 $41 $8 $0 $0 $205 85%
Biomass Digesters (50 MW) $64 $47 $0 $0 $0 $111 90%
CCCT—1x1 (270 MW) $27 $6 $67 $0 $7 $106 65%
CCCT—2x1 (580 MW) $24 $7 $66 $0 $7 $104 65%
Combined Heat and Power (100 MW) $27 $11 $74 $0 $0 $111 93%
Distributed Generation—Grid Sync (15 MW) $1,941 $10,305 $0 $0 $0 $12,246 0%
Distributed Generation—Load Shed (10 MW) $0 $10,305 $0 $0 $0 $10,305 0%
Geothermal—Idaho (26 MW) $107 $41 $0 $0 $0 $148 92%
Geothermal—Nevada (26 MW) $101 $41 $0 $0 $0 $142 92%
Geothermal—Oregon (26 MW) $104 $41 $0 $0 $0 $145 92%
IGCC (550 MW) $90 $24 $27 $0 $25 $166 85%
Low Drop/Small Hydro New (10 MW) $124 $20 $0 $0 $0 $144 45%
Pulverized Coal (600 MW) $63 $16 $29 $0 $26 $133 88%
Pulverized Coal w/Carbon Capture and Sequestration (455 MW) $145 $48 $40 $0 $5 $238 85%
Pumped Storage Fueled by LL Wind $173 $18 $0 $49 $0 $239 25%
SCCT—Industrial Frame (170 MW) $170 $29 $116 $0 $13 $328 6%
SCCT—Large Aero (100 MW) $174 $42 $86 $0 $10 $312 10%
SCCT—Small Aero (47 MW) $178 $50 $92 $0 $8 $327 8%
Solar—Concentrating Energy (100 MW) $206 $84 $0 $0 $0 $290 18%
Solar—Concentrating Energy Storage (100 MW) $202 $63 $0 $0 $0 $265 28%
Solar—Flat Plate PV Distributed (10 MW) 2 $227 $84 $0 $0 $0 $311 17%
Solar—Flat Plate PV Utility (10 MW) $117 $38 $0 $0 $0 $154 19%
Solar—Flat Plate PV Utility (1 MW) $179 $41 $0 $0 $0 $220 19%
Solar—Flat Plate Tracking PV Utility (1 MW) $153 $34 $0 $0 $0 $187 24%
Solar—Flat Plate Tracking PV Utility (10 MW) $102 $31 $0 $0 $0 $133 24%
Transmission—Boardman to Hemingway (350 MW)3 $20 $2 $0 $68 $0 $89 34%
Wind—Eastern Oregon (100 MW) $165 $47 $0 $0 $0 $212 26%
Wind—Magic Valley (100 MW) $125 $44 $0 $0 $0 $169 26%
Wind—Southeast Idaho(100 MW) $125 $44 $0 $0 $0 $169 26%
1 Includes fixed and variable costs and property taxes.
2 Approximately 2,500 4-kW PV systems.
3 350-MW average, 500-MW summer, and 200-MW winter.

Supply-Side Resource Data Idaho Power Company
Page 90 2013 Integrated Resource Plan—Appendix C
30-Year Levelized Capacity (fixed) Cost per kW/Month
Supply-Side Resources Cost of Capital Non-Fuel O&M1 Fuel Emission Adders Total Cost per kW
Advanced Nuclear (250 MW) $97 $25 $0 $0 $122
Biomass Digesters (50 MW) $42 $16 $0 $0 $58
CCCT—1x1 (270 MW) $13 $2 $0 $0 $14
CCCT—2x1 (580 MW) $11 $2 $0 $0 $13
Combined Heat and Power (100 MW) $18 $2 $0 $0 $21
Distributed Generation—Grid Sync (15 MW) $1 $8 $0 $0 $9
Distributed Generation—Load Shed (10 MW) $0 $8 $0 $0 $8
Geothermal—Idaho (26 MW) $72 $23 $0 $0 $95
Geothermal—Nevada (26 MW) $68 $22 $0 $0 $90
Geothermal—Oregon (26 MW) $70 $23 $0 $0 $93
IGCC (550 MW) $56 $9 $0 $0 $64
Low Drop/Small Hydro New (10 MW) $41 $5 $0 $0 $46
Pulverized Coal (600 MW) $40 $6 $0 $0 $47
Pulverized Coal w/Carbon Capture and Sequestration (455 MW) $90 $24 $0 $0 $114
Pumped Storage Fueled by LL Wind $32 $3 $0 $0 $35
SCCT—Industrial Frame (170 MW) $7 $1 $0 $0 $9
SCCT—Large Aero (100 MW) $13 $3 $0 $0 $15
SCCT—Small Aero (47 MW) $10 $2 $0 $0 $13
Solar—Concentrating Energy (100 MW) $56 $11 $0 $0 $67
Solar—Concentrating Energy Storage (100 MW) $80 $13 $0 $0 $93
Solar—Flat Plate PV Distributed (10 MW)1 $49 $10 $0 $0 $59
Solar—Flat Plate PV Utility (1 MW) $32 $6 $0 $0 $38
Solar—Flat Plate PV Utility (10 MW) $27 $5 $0 $0 $32
Solar—Flat Plate Tracking PV Utility (1 MW) $35 $6 $0 $0 $41
Solar—Flat Plate Tracking PV Utility (10 MW) $29 $5 $0 $0 $35
Transmission—Boardman to Hemingway (350 MW)2 $5 $0 $0 $0 $5
Wind—Eastern Oregon (100 MW) $31 $7 $0 $0 $38
Wind—Magic Valley (100 MW) $24 $6 $0 $0 $30
Wind—Southeast Idaho(100 MW) $24 $6 $0 $0 $30
1 Approximately 2,500 4-kW PV systems.
2 350-MW average, 500-MW summer, and 200-MW winter.

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 91
Resource Advantages and Disadvantages
Resource Type Advantages Disadvantages
Biomass • Renewable resource
• No harmful emissions
• Minimum fuel risk
• Low, variable operating costs
• Baseload generation (90%+ capacity factor)
• Limited number of sites
• Uncertainty surrounding future tax incentives
• Fuel supply risk
Coal
Pulverized

• Abundant, low-cost fuel
• Less price volatility than natural gas
• Proven and reliable technology
• Dispatchable resource
• Well suited for baseload operations

• Potential lack of public acceptance
• Significant particulate and gas emissions, particularly CO2
• Significant capital investment
• Long construction lead times
• Lengthy environmental permitting and siting processes
Advanced Technology
• Abundant, low cost fuel
• Potentially lower greenhouse gas emissions if CO2 is sequestered
• Potential for financial incentives
• Dispatchable resource
• New, unproven technologies
• Higher capital costs than pulverized coal
• Long construction lead times
Distributed Generation
• Utilize existing backup generators at customer sites
• Dispatchable resource
• Provides operating reserves
• More expensive than other resource options
• Limited number of sites
• Fuel price risk and volatility
• Existing air quality permits may need to be modified
• Small size, many sites would be required
Geothermal • Renewable resource
• No harmful emissions
• Minimum fuel risk (once developed)
• Low, variable operating costs
• Baseload generation (90%+ capacity factor)
• Limited number of sites
• High exploration costs due to drilling risks
• Uncertainty surrounding future tax incentives
Hydro • Renewable resource
• No fuel cost
• No harmful emissions
• Low, variable operating costs
• Limited number of sites
• Future development is limited to small sites or at existing dams without power generation
• Fish and other environmental issues
In-stream Generation
• Renewable resource
• No harmful emissions
• No fuel cost
• Small size, many sites would be required
• Environmental impact and permitting
• High maintenance cost
Supply-Side Resource Data Idaho Power Company
Page 92 2013 Integrated Resource Plan—Appendix C
Resource Type Advantages Disadvantages
Natural Gas
CCCT

• Proven and reliable technology
• Dispatchable resource
• Provides operating reserves necessary for integration of renewable generation
• More efficient than a SCCT
• Greater than 50% reduction in CO2 emissions per MWh of output compared to conventional pulverized coal technology

• Fuel price risk and volatility
• Potential fuel supply and transportation issues
SCCT • Dispatchable resource
• Proven, reliable resource
• Low capital cost
• Short construction lead times
• Ideal for peaking service
• High variable operating cost
• Fuel price risk and volatility
• Less efficient than a CCCT

Nuclear • Forecasted low fuel costs
• Forecasted adequate fuel availability
• Lack of greenhouse gas emissions
• Potential low cost of production
• Proven technology (existing reactor types)
• Lack of public acceptance
• Safety concerns
• Waste disposal
• Construction cost uncertainties and the potential for construction cost overruns
• Security concerns
Solar (General)
• Renewable resource
• No fuel cost
• No harmful emissions
• Low, variable operating costs
• Generation would match well with summer peak loads.
• More expensive than other resource options
• Poor generation during winter months
• Intermittent and non-dispatchable resource
• Inefficient use of limited firm transmission capacity
• Limited utility scale projects exist
Parabolic Trough • Can be built with thermal storage • Utility scale production is limited
Power Tower • By using molten salt, thermal storage can be built integrally into the system • Utility scale production is unproven
• Requires land slope of 1% or less
Parabolic Dish • Off-grid electricity production in remote areas • Not suitable for storage options
• Unproven technology
Photovoltaic • Proven & reliable technology
• Suitable for distributed generation
• Cloud cover creates a rapid power drop-off
• Utility scale projects are only practical up to 10 MW
Transmission • Provides peak-hour capacity
• Can help integrate renewable generation
• Lower capital cost compared to other resources
• Expanded capacity for off-system sales
• Stability associated with possible long-term firm contracts (sales and purchases)
• Siting is difficult with impact to many land owners
• Exposure to potential market volatility
• Considerable lead times required
Wind • Renewable resource
• No fuel cost
• No harmful emissions
• Low, variable operating costs
• Limited number of good sites in southern Idaho
• Intermittent and non-dispatchable resource
• Inefficient use of limited firm transmission capacity
• Avian and aesthetic impacts
• Uncertainty surrounding future tax incentives

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 93
Resource Peak Hour Shape
July 25, 2018: Peak Load = 3,437 MW

Capacity Factors for Solar PV
The following tables show capacity factors for solar photovoltaic (PV) panels located in Boise, Idaho.
The data is from a tool, PVWatts™, developed by the Nation Renewable Energy Laboratory (NREL).
NREL describes PVWatts in the following manner:
NREL’s PVWatts™ calculator determines the energy production and cost savings of grid-connected photovoltaic (PV) energy systems throughout the world. It allows
homeowners, installers, manufacturers, and researchers to easily develop estimates of
the performance of hypothetical PV installations.
The PVWatts calculator works by creating hour-by-hour performance simulations that
provide estimated monthly and annual energy production in kilowatts and energy value. Users can select a location and choose to use default values or their own system
parameters for size, electric cost, array type, tilt angle, and azimuth angle. In addition,
the PVWatts calculator can provide hourly performance data for the selected location.
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Hour Ending1_1 NW Transmission (200 MW)1_2 SCCT (211 MW)1_3 CHP (211 MW)1_4 Canal Drop Hydro (299 MW)1_5 Distributed Solar PV (513 MW)1_6 Utility Solar PV (625 MW)1_7 CCCT (211 MW)1_8 LL Wind Pumped Storage (200 MW)
Distributed PVCanalDrop Hydro
CHP
Utility PV
NW Transmission
CCCT
SCCT
Pumped Storage Fueled by LL Wind
On-PeakHours 3-7 PMLoad
Supply-Side Resource Data Idaho Power Company
Page 94 2013 Integrated Resource Plan—Appendix C
Using typical meteorological year weather data for the selected location, the PVWatts
calculator determines the solar radiation incident of the PV array and the PV cell
temperature for each hour of the year. The DC energy for each hour is calculated from
the PV system DC rating and the incident solar radiation and then corrected for the PV cell temperature. The AC energy for each hour is calculated by multiplying the DC
energy by the overall DC-to-AC derate factor and adjusting for inverter efficiency as a
function of load. Hourly values of AC energy are then summed to calculate monthly and
annual AC energy production.
The following NREL PVWatts data are for a solar PV array in the Boise area. The PV oriented to the southwest is equivalent to a north-based azimuth of 225 degrees. The PV oriented to the south is
equivalent to a north-based azimuth of 180 degrees. The following link displays the PVWatts data in
Boise: http://rredc.nrel.gov/solar/calculators/PVWATTS/version1/US/Idaho/Boise.html.
Capacity Factors for Southerly Oriented PV in Boise
Time Hour Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
12 am–1 am 1 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
1 am–2 am 2 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
2 am–3 am 3 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
3 am–4 am 4 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
4 am–5 am 5 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
5 am–6 am 6 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
6 am–7 am 7 0.0% 0.0% 0.0% 0.0% 0.1% 0.3% 0.1% 0.0% 0.0% 0.0% 0.0% 0.0%
7 am–8 am 8 0.0% 0.0% 0.7% 6.4% 9.6% 10.9% 8.1% 6.6% 6.2% 3.5% 0.2% 0.0%
8 am–9 am 9 1.3% 7.4% 15.9% 23.1% 25.7% 26.4% 24.2% 24.8% 24.3% 20.6% 9.8% 1.9%
9 am–10 am 10 15.5% 25.4% 31.1% 38.4% 38.8% 41.6% 39.2% 41.8% 41.5% 36.5% 23.1% 15.3%
10 am–11 am 11 26.1% 39.5% 41.8% 48.0% 49.3% 49.8% 52.6% 51.7% 50.1% 48.0% 36.2% 28.0%
11 am–12 pm 12 33.4% 47.6% 51.3% 55.2% 54.5% 56.2% 59.1% 61.0% 56.2% 54.5% 41.0% 35.9%
12 pm–1 pm 13 36.7% 51.2% 54.6% 54.9% 58.3% 60.6% 62.0% 63.0% 60.7% 59.3% 42.9% 38.9%
1 pm–2 pm 14 39.7% 47.7% 50.9% 56.2% 58.8% 57.9% 62.6% 62.6% 61.8% 52.7% 43.1% 37.6%
2 pm–3 pm 15 32.5% 44.3% 50.2% 54.3% 52.4% 53.1% 58.0% 58.9% 55.5% 49.7% 34.8% 32.3%
3 pm–4 pm 16 25.3% 32.3% 39.8% 42.3% 41.3% 43.9% 49.0% 49.8% 47.1% 38.0% 21.8% 22.1%
4 pm–5 pm 17 11.4% 20.1% 25.6% 28.7% 31.6% 31.3% 34.5% 35.2% 30.7% 21.0% 8.2% 7.4%
5 pm–6 pm 18 0.6% 5.3% 11.4% 14.6% 15.5% 17.0% 18.5% 17.5% 12.6% 4.0% 0.1% 0.0%
6 pm–7 pm 19 0.0% 0.0% 0.1% 0.2% 1.0% 1.8% 1.5% 0.4% 0.0% 0.0% 0.0% 0.0%
7 pm–8 pm 20 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
8 pm–9 pm 21 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
9 pm–10 pm 22 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
10 pm–11 pm 23 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
11 pm–12 am 24 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
Average 9.3% 13.4% 15.6% 17.6% 18.2% 18.8% 19.6% 19.7% 18.6% 16.2% 10.9% 9.1%
Annual Average 15.6%
All values are in Mountain Standard Time (MST) and have not been adjusted for Daylight Savings Time (DST). DST begins on the second Saturday in March and ends the first Sunday in November.

Idaho Power Company Supply-Side Resource Data
2013 Integrated Resource Plan—Appendix C Page 95
Capacity Factors for Southwesterly Oriented PV in Boise
Time Hour Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
12 am–1 am 1 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
1 am–2 am 2 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
2 am–3 am 3 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
3 am–4 am 4 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
4 am–5 am 5 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
5 am–6 am 6 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
6 am–7 am 7 0.0% 0.0% 0.0% 0.0% 0.1% 0.3% 0.1% 0.0% 0.0% 0.0% 0.0% 0.0%
7 am–8 am 8 0.0% 0.0% 0.0% 1.1% 2.2% 2.8% 1.8% 0.5% 0.1% 0.0% 0.0% 0.0%
8 am–9 am 9 0.0% 0.1% 1.1% 4.4% 5.2% 6.1% 2.8% 1.9% 1.3% 0.4% 0.1% 0.0%
9 am–10 am 10 1.8% 3.3% 11.4% 16.6% 18.7% 18.9% 15.4% 15.2% 14.7% 13.5% 6.9% 1.7%
10 am–11 am 11 14.3% 19.7% 25.2% 31.6% 33.6% 33.5% 33.0% 32.0% 31.1% 29.6% 21.6% 14.9%
11 am–12 pm 12 24.2% 33.2% 38.9% 43.9% 44.7% 45.9% 46.8% 47.7% 43.9% 42.1% 30.8% 25.8%
12 pm–1 pm 13 30.7% 42.3% 47.2% 49.4% 53.6% 55.6% 55.9% 56.1% 53.8% 52.0% 37.0% 32.5%
1 pm–2 pm 14 36.6% 44.0% 48.9% 55.6% 59.6% 58.8% 62.8% 62.0% 60.8% 51.4% 41.3% 35.0%
2 pm–3 pm 15 32.9% 45.2% 53.1% 59.2% 58.8% 59.7% 64.7% 64.7% 60.7% 54.1% 37.1% 33.3%
3 pm–4 pm 16 28.7% 36.8% 46.9% 51.5% 51.8% 55.4% 61.8% 62.0% 58.6% 47.4% 26.6% 26.3%
4 pm–5 pm 17 16.3% 27.3% 35.8% 41.3% 48.8% 47.6% 52.9% 53.4% 47.1% 33.5% 13.8% 11.7%
5 pm–6 pm 18 1.8% 12.2% 24.6% 30.1% 34.1% 38.5% 41.4% 40.3% 32.1% 15.1% 1.0% 0.0%
6 pm–7 pm 19 0.0% 0.0% 8.1% 15.3% 17.5% 23.1% 25.7% 21.7% 10.3% 0.0% 0.0% 0.0%
7 pm–8 pm 20 0.0% 0.0% 0.0% 0.1% 2.9% 6.6% 8.5% 2.7% 0.0% 0.0% 0.0% 0.0%
8 pm–9 pm 21 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
9 pm–10 pm 22 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
10 pm–11 pm 23 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
11 pm–12 am 24 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%
Average 9.3% 7.8% 11.0% 14.2% 16.7% 18.0% 18.9% 19.7% 19.2% 17.3% 14.1% 9.0%
Annual Average 14.5%
All values are in MST and have not been adjusted for DST. DST begins on the second Saturday in March and ends the first Sunday in November.

The tables show a PV oriented to the southwest produces more energy in the months of June and July. The PV oriented to the south generates more energy in all other months, and the south orientation
generates more energy annually. Annual average capacity factors for a southern PV orientation in Boise
is 15.6 percent, and for a southwestern orientation is 14.5 percent.
The tables indicate the southwest orientation in Boise has a 25.7 percent capacity factor from 6:00 to 7:00 pm in July and the south orientation has a 1.5 percent capacity factor during the same hour in July. Even though the southwestern exposure has a considerably greater capacity factor in late afternoon in
July, the southwestern exposure capacity factor is still only 26 percent during the 6:00 to 7:00 pm hour
in July. To meet a 100 MW capacity deficit during the 6:00 to 7:00 pm hour in July would require
almost 400 MW of installed nameplate solar PV according to the NREL data. It is likely that the 90th percentile exceedance criteria used by Idaho Power for capacity resource planning would further increase the quantity of solar generation needed to address a capacity deficit.

Fuel Data Idaho Power Company
Page 96 2013 Integrated Resource Plan—Appendix C
FUEL DATA
Natural Gas and Coal Price Forecast
Year Sumas (Expected) Sumas (High) Sumas (Low) Regional Coal
2013 $4.46 $5.79 $3.13 $2.32
2014 $4.76 $6.17 $3.36 $2.44
2015 $5.06 $6.56 $3.57 $2.42
2016 $5.19 $6.71 $3.66 $2.45
2017 $5.40 $6.98 $3.81 $2.56
2018 $5.64 $7.29 $3.99 $2.68
2019 $5.98 $7.73 $4.23 $2.64
2020 $6.34 $8.18 $4.49 $2.70
2021 $6.87 $8.87 $4.87 $2.79
2022 $7.51 $9.69 $5.32 $2.89
2023 $8.05 $10.40 $5.71 $2.98
2024 $8.52 $11.00 $6.04 $3.07
2025 $9.05 $11.68 $6.42 $3.17
2026 $9.56 $12.34 $6.78 $3.27
2027 $10.14 $13.08 $7.19 $3.38
2028 $10.61 $13.69 $7.53 $3.48
2029 $11.14 $14.38 $7.91 $3.59
2030 $11.74 $15.15 $8.33 $3.71
2031 $12.34 $15.93 $8.76 $3.87
2032 $13.03 $16.81 $9.25 $4.00

Sumas Natural Gas and Coal Price Forecast

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Idaho Power Company Fuel Data
2013 Integrated Resource Plan—Appendix C Page 97
Sumas Natural Gas Price Forecast Comparison (planning case)

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Existing Resource Data Idaho Power Company
Page 98 2013 Integrated Resource Plan—Appendix C
EXISTING RESOURCE DATA
Hydroelectric and Thermal Plant Data
Nameplate
Hydroelectric Power Plans kVA kW Normal Rating kW4 Emergency Rating kW5
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 2,5001 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 12,5001 12,500 12,500
Swan Falls .................................................................... 28,600 27,170 24,1703 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)6,7
Thermal, Natural Gas, and Diesel Power Plans Gross kVA Gross kW kW Summer kW Winter kW
Bridger (Idaho Power share) .................................................. 811,053 770,501 703,667 703,667
Boardman (Idaho Power share) ............................................. 67,600 64,200 57,800 58,300
Valmy (Idaho Power share) ................................................... 315,000 283,500 261,000 261,000
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
1 A power factor rating of 0.8 is assumed on four units (Clear Lake, Shoshone Falls unit 2, and Thousand Springs units 1 and 2) with a total kVA rating of 6,127 kVA where there 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 seasonal or other de-ratings.
Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 99
Qualifying Facility Data (PURPA)
Cogeneration and Small Power Production Projects
Status as of June 17, 2013.
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 Lowline Canal 2.50 May-1985 Apr-2005
Barber Dam 3.70 Apr-1989 Apr-2024 Lowline Midway Hydro 7.97 Aug-2007 Aug-2027
Birch Creek 0.05 Nov-1984 Oct-2019 Lowline #2 2.79 Apr-1988 Apr-2023
Black Canyon #3 0.14 Apr-1984 Apr-2019 Magic Reservoir 9.07 Jun-1989 May-2024
Blind Canyon 1.50 Dec-1994 Dec-2014 Malad River 0.62 May-1984 Apr-2019
Box Canyon 0.36 Feb-1984 Feb-2019 Marco Ranches 1.20 Aug-1985 Jul-2020
Briggs Creek 0.60 Oct-1985 Oct-2020 Mile 28 1.50 Jun-1994 May-2029
Bypass 9.96 Jun-1988 Jun-2023 Mill Creek 0.80 Nov-2011 Jun-2017
Canyon Springs 0.13 Oct-1984 Non firm Mitchell Butte 2.09 May-1989 May-2024
Cedar Draw 1.55 Jun-1984 May-2019 Mora Drop 1.90 Oct-2006 Sep-2026
Clark Canyon 4.70 Dec-2013 Estimated Mud Creek S&S 0.52 Feb-1982 Feb-2017
Clear Springs Trout 0.52 Nov-1983 Oct-2018 Mud Creek White 0.21 Jan-1986 Jan-2021
Crystal Springs 2.44 Apr-1986 Mar-2021 Owyhee Dam CSPP 5.00 Aug-1985 Aug-2015
Curry Cattle Company 0.22 Jun-1983 Jun-2018 Pigeon Cove 1.89 Oct-1984 Oct-2019
Dietrich Drop 4.50 Aug-1988 Aug-2023 Pristine Springs 0.13 May-2005 Apr-2015
Elk Creek 2.00 May-1986 May-2021 Pristine Springs #3 0.20 May-2005 Apr-2015
Falls River 9.10 Aug-1993 Aug-2028 Reynolds Irrigation 0.26 May-1986 May-2021
Fargo Drop 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 Mar-2024
Fisheries Development Co 0.26 Jul-1990 Non firm Sagebrush 0.43 Sep-1985 Aug-2020
Geo Bon #2 0.93 Nov-1986 Nov-2021 Sahko Hydro 0.50 Jun-2006 Feb-2021
Hailey CSPP 0.06 Jun-1985 Jun-2020 Schaffner 0.53 Aug-1986 Jul-2021
Hazelton A 8.10 Jun-1990 Mar-2026 Shingle Creek 0.22 Aug-1983 Jul-2018
Hazelton B 7.60 May-1993 Apr-2028 Shoshone #2 0.58 May-1996 Apr-2031
Horseshoe Bend Hydroelectric 9.50 Sep-1995 Sep-2030 Shoshone CSPP 0.37 Jun-1982 Jun-2017
Jim Knight 0.34 Jun-1985 Jun-2020 Snake River Pottery 0.07 Nov-1984 Nov-2019
Kasel and Witherspoon 0.90 Mar-1984 Feb-2019 Snedigar 0.54 Jan-1985 Dec-2019
Koyle Small Hydro 1.25 Apr-1984 Mar-2019 Tiber Dam 7.50 Jun-2004 May-2024
Lateral # 10 2.06 May-1985 Apr-2020 Trout—Co 0.24 Dec-1986 Nov-2021
Lemoyne 0.08 Jun-1985 Jun-2020 Tunnel #1 7.00 Jun-1993 May-2028
Little Wood Rvr Res 2.85 Feb-1985 Feb-2020 White Water Ranch 0.16 Aug-1985 Jul-2020
Littlewood–Arkoosh 0.87 Aug-1986 Jul-2021 Wilson Lake Hydro 8.40 May-1993 May-2028
Total Hydro Nameplate Rating 147.92 MW
Thermal Projects
Magic Valley Natural Gas 10.00 Nov-1996 Nov-2016 TASCO—Nampa Natural Gas 2.00 Sep-2003 Non firm
Magic West Natural Gas 10.00 Dec-1996 Nov-2016 TASCO—Twin Falls Natural Gas 3.00 Aug-2001 Non firm
Simplot Pocatello Cogen 15.90 Mar-2013 Feb-2016
Total Thermal Nameplate Rating 40.90 MW

Existing Resource Data Idaho Power Company
Page 100 2013 Integrated Resource Plan—Appendix C
Contract Contract
Project MW On-line Date End Date Project MW On-line Date End Date
Biomass Projects
B6 Anaerobic Digester 2.28 Aug-2009 Aug-2019 Hidden Hollow Landfill Gas 3.20 Oct-2006 Jan-2027
Bettencourt Dry Creek 2.25 Aug-2008 Aug-2018 Pocatello Waste 0.46 Dec-1985 Dec-2020
Big Sky West Dairy Digester 1.50 Jan-2009 Jan-2029 Rock Creek Dairy 4.00 May-2012 Aug-2027
Double A Digester Project 4.50 Jan-2012 Jan-2032 Tamarack CSPP 5.00 Jun-1983 May-2018
Total Biomass Nameplate Rating 23.19 MW
Wind Projects
Bennett Creek Wind Farm 21.00 Dec-2008 Dec-2028 Milner Dam Wind 19.92 Feb-2011 Feb-2031
Burley Butte Wind 21.30 Feb-2011 Feb-2031 Oregon Trail Wind 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 10.50 Mar-2009 Mar-2029 Pilgrim Stage Station Wind 10.50 Jan-2011 Jan-2031
Cold Springs Windfarm 23.00 Dec-2012 Dec-2032 Rockland Wind Project 80.00 Dec-2011 Dec-2031
Desert Meadow Windfarm 23.00 Dec-2012 Dec-2032 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 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 12.00 Jan-2011 Jan-2031
High Mesa 40.00 Dec-2012 Dec-2032 Tuana Gulch Wind 10.50 Jan-2011 Jan-2031
Horseshoe Bend Wind Park 9.00 Feb-2006 Feb-2026 Tuana Springs Expansion 35.70 May-2010 Jun-2030
Hot Springs Wind Farm 21.00 Dec-2008 Dec-2028 Two Ponds Windfarm 23.00 Dec-2012 Dec-2012
Lime Wind Energy 3.00 Dec-2011 Dec-2031 Yahoo Creek Wind Park 21.00 Dec-2010 Dec-2030
Mainline Windfarm 23.00 Dec-2012 Dec-2032
Total Wind Nameplate Rating 576.92 MW
Total Nameplate Rating 788.93 MW
The above is a summary of the nameplate rating for the CSPP projects under contract with Idaho Power as of June 17, 2013. 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.

Power Purchase Agreement Data
Idaho Power Company Power Purchase Agreements Status as of April 1, 2013
Contract
Project MW On-Line Date End Date
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 September 2012 September 2037
Total geothermal nameplate MW rating ........................................................ 35
Total nameplate MW rating .............................................................................. 136
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.

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 101
Hydro Modeling Results (PDR580)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013 aMW
Brownlee HCC* 343.1 293.0 343.5 435.3 421.2 424.5 242.8 170.4 215.4 193.2 152.6 253.0 290.7
Oxbow HCC 143.5 127.9 150.4 181.0 168.9 171.1 103.2 78.0 98.7 88.8 69.4 106.5 123.9
Hells Canyon HCC 282.0 255.2 304.1 371.7 348.1 345.5 204.8 153.1 193.8 175.2 138.2 211.3 248.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 23.6 24.4 24.3 51.0 80.6 88.2 81.8 67.7 41.1 15.3 0.0 13.5 42.6
Bliss ROR 49.5 49.5 42.8 49.8 46.8 42.9 35.5 32.1 37.8 40.4 38.3 42.6 42.3
C .J. Strike ROR 64.4 64.9 57.1 64.4 62.0 53.6 38.3 34.8 45.3 51.5 50.5 55.4 53.5
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.9 35.0 28.5 34.6 33.1 29.2 23.1 19.4 24.2 26.3 24.7 29.5 28.5
Milner ROR 40.1 40.2 20.7 36.3 31.4 18.2 5.9 6.7 0.0 0.0 4.6 24.3 19.0
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.7 10.5 12.0 12.0 11.4
Swan Falls ROR 20.8 21.1 18.6 20.9 20.0 17.5 13.3 12.1 15.2 17.0 16.7 18.1 17.6
Twin Falls ROR 39.6 39.9 22.4 35.9 32.1 21.7 10.2 11.5 0.0 6.6 9.2 25.9 21.3
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 18.9 14.1 11.5 14.9 16.4 15.1 19.0 16.7
Upper Salmon 3&4 ROR 17.7 17.7 16.5 16.8 17.4 17.4 13.3 11.0 13.9 15.2 14.1 17.5 15.7
HCC Total 768.6 676.1 798.0 988.0 938.1 941.1 550.8 401.5 507.9 457.2 360.2 570.8 663.2
ROR Total 348.3 349.8 285.5 370.9 388.0 357.5 283.2 258.3 236.1 228.4 209.3 284.5 300.0
Total 1116.9 1025.9 1083.5 1358.9 1326.0 1298.6 834.0 659.8 744.0 685.6 569.5 855.3 963.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource Type 1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014 aMW
Brownlee HCC* 342.2 292.5 342.6 435.0 420.5 423.9 242.2 169.8 213.6 194.0 152.9 247.9 289.8
Oxbow HCC 143.1 127.7 150.0 180.9 168.6 170.9 103.0 77.7 97.7 88.9 69.3 104.3 123.5
Hells Canyon HCC 281.3 254.9 303.3 371.4 347.5 345.1 204.3 152.6 191.7 175.4 138.1 207.0 247.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 22.3 24.2 23.6 50.7 79.6 88.1 81.8 67.6 41.0 15.2 0.0 11.0 42.1
Bliss ROR 49.0 49.3 42.3 49.6 46.8 42.8 35.3 31.9 37.6 40.2 38.1 42.4 42.1
C .J. Strike ROR 64.1 64.6 56.8 64.1 61.8 53.3 38.1 34.6 45.0 51.3 50.3 53.2 53.1
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.5 34.9 27.8 34.4 32.5 29.1 23.0 19.3 24.0 26.2 24.5 28.9 28.3
Milner ROR 38.2 39.9 18.7 36.0 30.5 18.2 5.9 6.7 0.0 0.0 4.6 20.1 18.2
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.7 10.5 12.0 12.0 11.4
Swan Falls ROR 20.5 21.0 18.5 20.8 19.9 17.4 13.3 12.1 15.1 16.9 16.5 17.5 17.5
Twin Falls ROR 37.9 39.7 21.8 35.7 31.2 21.7 10.2 11.5 0.0 6.6 9.2 22.1 20.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.2 18.8 14.1 11.4 14.8 16.3 15.0 18.5 16.6
Upper Salmon 3&4 ROR 17.7 17.7 16.5 16.8 17.4 17.3 13.2 10.9 13.8 15.1 14.0 17.0 15.6
HCC Total 766.6 675.1 795.9 987.3 936.5 939.9 549.5 400.1 502.9 458.3 360.3 559.2 661.0
ROR Total 341.9 348.4 280.6 369.3 384.4 356.6 282.6 257.5 235.0 227.5 208.3 269.4 296.8
Total 1108.5 1023.5 1076.5 1356.6 1320.8 1296.5 832.1 657.6 737.9 685.8 568.6 828.6 957.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 102 2013 Integrated Resource Plan—Appendix C
Hydro Modeling Results (PDR580) (continued)
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* 350.5 292.8 342.1 440.5 435.0 438.7 242.3 169.7 222.1 192.9 152.6 255.1 294.5
Oxbow HCC 146.5 127.9 149.8 183.1 174.2 176.7 103.0 77.7 100.3 89.0 69.4 107.4 125.4
Hells Canyon HCC 287.9 255.1 302.9 375.8 358.7 356.4 204.3 152.5 195.9 175.5 138.3 213.1 251.4
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 24.5 24.6 25.2 59.0 86.2 91.8 82.4 68.5 41.5 17.2 0.0 16.7 44.8
Bliss ROR 49.8 49.4 42.2 53.0 51.0 44.8 35.3 31.9 37.6 40.4 38.7 46.2 43.4
C .J. Strike ROR 65.3 65.1 56.9 68.0 66.4 55.2 38.0 34.5 44.9 51.6 50.8 58.6 54.6
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 35.2 34.9 27.8 37.4 36.7 30.2 23.0 19.2 23.9 26.4 24.7 32.1 29.3
Milner ROR 41.5 40.4 20.5 44.3 40.9 22.9 5.9 6.7 0.0 0.0 5.5 29.7 21.5
Shoshone Falls ROR 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 6.7 10.5 12.0 12.0 11.4
Swan Falls ROR 21.0 21.2 18.6 21.9 21.4 18.0 13.3 12.1 15.1 17.0 16.8 19.0 18.0
Twin Falls ROR 41.5 40.2 22.1 43.6 40.4 25.5 10.2 11.5 0.0 6.6 9.5 30.6 23.5
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 14.0 11.3 14.7 16.4 15.2 19.2 16.7
Upper Salmon 3&4 ROR 17.7 17.7 16.5 16.8 17.4 17.7 13.2 10.9 13.8 15.2 14.2 17.7 15.7
HCC Total 784.9 675.8 794.8 999.4 967.9 971.8 549.6 399.9 518.2 457.4 360.3 575.6 671.3
ROR Total 354.2 350.6 284.4 405.2 424.9 375.2 283.0 258.1 235.3 230.5 211.5 308.5 310.1
Total 1139.1 1026.4 1079.2 1404.6 1392.8 1347.0 832.6 658.0 753.5 687.9 571.8 884.1 981.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 349.6 295.1 341.2 440.2 434.2 438.2 241.7 156.9 216.9 193.3 152.6 254.6 292.9
Oxbow HCC 146.1 128.8 149.4 183.0 173.9 176.4 102.7 71.6 99.7 89.1 69.4 107.2 124.8
Hells Canyon HCC 287.2 257.0 302.1 375.6 358.1 356.0 203.8 141.1 195.7 175.8 138.3 212.6 250.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 24.3 24.4 25.0 58.8 86.0 91.8 82.3 64.3 42.2 17.4 0.0 20.6 44.8
Bliss ROR 49.5 49.2 42.0 52.9 50.8 44.7 35.2 28.1 37.4 40.4 38.7 48.5 43.1
C .J. Strike ROR 65.0 64.9 57.2 67.7 66.1 55.0 37.8 29.7 44.7 51.6 51.1 61.8 54.4
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 35.0 34.7 27.6 37.6 36.5 30.1 22.9 16.0 23.8 26.3 24.7 34.1 29.1
Milner ROR 41.2 40.2 20.1 43.9 40.6 22.5 5.9 0.0 0.0 0.0 5.5 36.0 21.3
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 21.0 21.1 18.6 21.8 21.3 17.9 13.2 10.4 15.0 17.0 16.9 19.9 17.8
Twin Falls ROR 41.3 39.9 21.7 43.3 40.2 25.3 10.2 0.0 0.0 6.6 10.0 36.1 22.9
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 13.9 8.8 14.6 16.4 15.1 19.1 16.4
Upper Salmon 3&4 ROR 17.7 17.7 16.4 16.8 17.4 17.7 13.1 8.8 13.7 15.2 14.1 17.7 15.5
HCC Total 782.9 680.9 792.7 998.8 966.2 970.6 548.2 369.6 512.2 458.2 360.3 574.4 667.9
ROR Total 352.7 349.2 283.2 404.0 423.4 374.1 282.2 212.5 235.1 230.6 212.2 332.5 307.6
Total 1135.6 1030.1 1075.9 1402.8 1389.6 1344.7 830.4 582.1 747.3 688.8 572.5 906.9 975.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 103
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* 349.0 292.0 338.8 440.0 433.1 437.7 241.2 156.4 215.0 193.5 152.4 254.5 292.0
Oxbow HCC 145.9 127.5 148.4 182.9 173.5 176.3 102.5 71.4 98.7 89.0 69.3 107.2 124.4
Hells Canyon HCC 286.7 254.5 300.2 375.4 357.2 355.6 203.4 140.6 193.6 175.6 138.0 212.5 249.4
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 24.1 24.2 24.8 58.2 85.5 91.4 82.2 64.2 42.5 17.3 0.0 20.6 44.6
Bliss ROR 49.4 49.1 41.8 51.6 50.4 44.6 35.0 28.0 37.3 40.2 38.7 48.2 42.9
C .J. Strike ROR 64.8 64.7 56.5 66.6 65.6 54.8 37.7 29.5 44.5 51.4 50.9 61.5 54.0
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.8 34.5 27.0 36.7 36.1 30.1 22.8 15.8 23.6 26.2 24.5 33.9 28.8
Milner ROR 41.0 40.0 18.2 42.1 40.0 22.3 5.9 0.0 0.0 0.0 5.5 36.0 20.9
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 21.1 18.4 21.5 21.2 17.9 13.1 10.4 15.0 16.9 16.8 19.8 17.8
Twin Falls ROR 41.1 39.6 20.4 41.7 39.6 25.0 10.2 0.0 0.0 6.6 10.0 36.2 22.5
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 13.8 8.7 14.5 16.3 15.0 19.1 16.4
Upper Salmon 3&4 ROR 17.7 17.7 16.1 16.8 17.4 17.7 13.0 8.7 13.6 15.1 14.0 17.7 15.5
HCC Total 781.6 674.0 787.4 998.3 963.8 969.6 547.1 368.4 507.2 458.1 359.7 574.2 665.8
ROR Total 351.5 348.0 277.8 396.4 420.3 372.9 281.4 211.7 234.8 229.7 211.5 331.7 305.6
Total 1133.1 1022.0 1065.2 1394.7 1384.1 1342.5 828.5 580.1 741.9 687.8 571.2 905.9 971.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 348.6 291.7 338.2 439.6 432.8 437.1 240.7 155.8 213.4 193.6 152.5 253.9 291.5
Oxbow HCC 145.7 127.4 148.2 182.8 173.4 176.0 102.3 71.1 97.8 89.0 69.3 106.9 124.2
Hells Canyon HCC 286.4 254.2 299.7 375.1 357.0 355.2 203.0 140.1 192.0 175.5 138.1 212.1 249.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 24.1 24.2 24.6 58.0 85.4 91.1 82.1 64.2 42.5 17.3 0.0 17.3 44.2
Bliss ROR 49.3 49.0 41.2 51.4 49.9 44.5 34.9 27.8 37.2 40.0 38.4 45.7 42.4
C .J. Strike ROR 64.7 64.5 56.3 66.4 64.8 54.4 37.5 29.3 44.2 51.0 50.5 58.5 53.5
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.8 34.4 26.6 35.4 35.7 30.0 22.6 15.7 23.5 26.0 24.4 31.8 28.4
Milner ROR 41.0 40.0 15.5 40.1 38.8 22.3 5.9 0.0 0.0 0.0 5.5 30.6 20.0
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 20.9 18.4 21.4 21.0 17.7 13.1 10.3 14.9 16.9 16.7 19.0 17.6
Twin Falls ROR 41.2 39.6 19.2 39.3 38.6 24.6 10.2 0.0 0.0 6.6 9.6 31.5 21.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 13.8 8.6 14.3 16.1 14.9 19.2 16.3
Upper Salmon 3&4 ROR 17.7 17.7 15.8 16.8 17.4 17.7 13.0 8.6 13.5 15.0 14.0 17.7 15.4
HCC Total 780.7 673.3 786.1 997.5 963.1 968.3 546.0 367.0 503.2 458.1 359.9 572.9 664.7
ROR Total 351.4 347.4 272.2 390.0 416.1 371.4 280.8 210.9 233.9 228.6 210.1 310.0 301.9
Total 1132.1 1020.7 1058.3 1387.5 1379.2 1339.7 826.8 577.9 737.1 686.7 570.0 882.9 966.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 104 2013 Integrated Resource Plan—Appendix C
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* 347.7 291.4 336.7 438.8 432.5 436.6 240.1 155.3 211.9 193.8 152.6 253.5 290.9
Oxbow HCC 145.4 127.2 147.5 182.5 173.3 175.8 102.1 70.8 97.0 88.9 69.3 106.7 123.9
Hells Canyon HCC 285.7 253.9 298.4 374.5 356.7 354.8 202.5 139.6 190.4 175.4 138.1 211.7 248.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 23.9 24.0 24.3 57.8 85.2 90.7 82.1 64.1 42.4 17.7 0.0 15.7 44.0
Bliss ROR 49.1 48.8 40.8 51.0 49.7 44.4 34.7 27.7 37.0 39.9 38.2 44.6 42.2
C .J. Strike ROR 64.4 64.3 55.7 66.1 64.5 54.1 37.2 29.1 44.0 50.9 49.9 57.0 53.1
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.6 34.2 26.2 34.5 35.5 29.8 22.5 15.5 23.3 25.9 24.1 30.7 28.1
Milner ROR 40.7 39.6 14.7 36.2 38.6 21.7 5.9 0.0 0.0 0.0 5.5 28.0 19.2
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 20.8 20.8 18.2 21.4 20.9 17.7 13.0 10.2 14.8 16.8 16.4 18.6 17.5
Twin Falls ROR 40.9 39.3 18.4 36.2 38.4 24.2 10.2 0.0 0.0 6.6 9.5 29.1 21.1
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 13.7 8.5 14.2 16.0 14.7 19.2 16.3
Upper Salmon 3&4 ROR 17.7 17.7 15.5 16.8 17.4 17.7 12.9 8.5 13.4 14.9 13.8 17.7 15.3
HCC Total 778.8 672.5 782.6 995.8 962.5 967.2 544.7 365.7 499.2 458.1 360.0 571.9 663.2
ROR Total 349.8 345.8 268.4 381.2 414.7 369.4 279.9 210.0 232.9 228.4 208.2 299.3 299.0
Total 1128.6 1018.3 1051.0 1377.0 1377.2 1336.6 824.6 575.7 732.1 686.5 568.2 871.2 962.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 346.8 290.9 336.4 437.2 432.2 436.0 239.5 154.6 210.5 193.9 152.7 252.9 290.3
Oxbow HCC 145.0 127.1 147.4 181.8 173.2 175.6 101.8 70.6 96.3 88.9 69.3 106.5 123.6
Hells Canyon HCC 284.9 253.6 298.2 373.1 356.5 354.3 202.0 139.1 189.0 175.4 138.1 211.2 247.9
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 23.7 23.7 23.7 56.4 84.9 90.4 82.1 64.0 42.4 17.3 0.0 14.5 43.6
Bliss ROR 48.8 48.6 40.8 50.6 49.5 44.2 34.6 27.5 36.8 39.8 38.1 43.7 41.9
C .J. Strike ROR 64.0 64.0 55.6 65.6 64.3 53.8 37.0 28.9 43.7 50.6 49.7 55.7 52.7
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.4 34.0 26.2 34.2 35.3 29.6 22.4 15.4 23.1 25.7 24.0 29.9 27.9
Milner ROR 40.4 39.3 14.8 35.4 38.3 21.1 5.9 0.0 0.0 0.0 5.5 26.0 18.9
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 20.4 20.5 18.2 21.2 20.9 17.6 12.9 10.2 14.8 16.8 16.3 18.2 17.3
Twin Falls ROR 40.6 39.0 18.4 35.2 38.1 24.0 10.2 0.0 0.0 6.6 9.5 27.3 20.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.2 13.6 8.4 14.1 15.9 14.6 19.2 16.2
Upper Salmon 3&4 ROR 17.7 17.7 15.5 16.8 17.4 17.6 12.8 8.4 13.2 14.8 13.7 17.7 15.3
HCC Total 776.7 671.6 782.0 992.1 961.8 965.9 543.3 364.3 495.7 458.2 360.1 570.6 661.9
ROR Total 347.7 343.9 267.8 376.6 413.3 367.4 279.2 209.2 231.8 227.2 207.5 290.9 296.9
Total 1124.4 1015.5 1049.8 1368.7 1375.0 1333.3 822.5 573.5 727.5 685.4 567.6 861.5 958.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 105
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* 345.7 290.4 335.4 433.8 431.9 435.4 238.8 154.0 207.9 194.5 152.6 252.5 289.4
Oxbow HCC 144.5 126.8 147.0 180.4 173.0 175.4 101.5 70.2 94.9 88.9 69.2 106.3 123.2
Hells Canyon HCC 284.1 253.1 297.4 370.5 356.2 353.8 201.5 138.5 186.2 175.4 137.9 210.9 247.1
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 23.5 23.5 22.3 56.1 84.5 89.8 82.1 63.9 42.2 16.5 0.0 13.2 43.1
Bliss ROR 48.6 48.3 40.4 50.4 49.3 44.1 34.4 27.3 36.6 39.6 37.7 43.2 41.7
C .J. Strike ROR 63.7 63.6 55.3 64.4 63.9 53.4 36.8 28.6 43.5 50.4 49.5 54.3 52.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 34.1 33.8 25.9 33.8 35.1 29.5 22.2 15.2 23.0 25.6 23.7 29.4 27.6
Milner ROR 40.2 38.9 14.1 35.0 37.9 20.8 5.9 0.0 0.0 0.0 5.1 23.8 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 12.0 12.0 11.0
Swan Falls ROR 20.3 20.4 18.1 20.9 20.8 17.5 12.9 10.1 14.7 16.7 16.2 17.8 17.2
Twin Falls ROR 40.3 38.6 17.2 34.8 37.8 23.6 10.2 0.0 0.0 6.6 9.3 25.6 20.3
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.1 13.4 8.2 14.0 15.8 14.4 18.9 16.1
Upper Salmon 3&4 ROR 17.7 17.7 15.3 16.8 17.4 17.6 12.7 8.3 13.1 14.7 13.5 17.4 15.2
HCC Total 774.3 670.3 779.8 984.7 961.1 964.6 541.8 362.7 489.0 458.8 359.7 569.7 659.7
ROR Total 346.1 341.9 263.2 373.4 411.3 365.3 278.3 208.0 230.9 225.6 205.5 282.3 294.3
Total 1120.4 1012.2 1043.0 1358.1 1372.3 1329.9 820.1 570.7 719.8 684.4 565.2 852.0 954.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 344.6 289.9 334.8 433.4 431.5 434.8 238.2 153.3 205.7 194.8 153.0 249.8 288.6
Oxbow HCC 144.1 126.6 146.7 180.3 172.9 175.1 101.3 69.9 93.7 88.9 69.3 105.2 122.8
Hells Canyon HCC 283.2 252.7 296.9 370.2 355.9 353.4 201.0 137.9 184.0 175.3 138.1 208.6 246.4
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 23.3 23.2 22.0 52.2 84.3 89.5 82.1 63.8 42.1 17.3 0.0 11.9 42.6
Bliss ROR 48.3 48.0 40.1 50.1 49.1 43.9 34.3 27.1 36.4 39.4 37.6 42.2 41.4
C .J. Strike ROR 63.3 63.3 54.9 64.1 63.6 53.2 36.6 28.4 43.2 50.2 49.2 52.8 51.9
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 33.9 33.6 25.7 33.4 34.9 29.4 22.1 15.1 22.8 25.5 23.6 28.4 27.4
Milner ROR 39.9 38.5 13.5 34.1 37.6 20.4 5.9 0.0 0.0 0.0 5.1 21.5 18.0
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 20.2 20.3 18.0 20.8 20.8 17.4 12.8 10.0 14.6 16.5 16.2 17.4 17.1
Twin Falls ROR 40.0 38.3 17.2 34.0 37.5 23.3 10.2 0.0 0.0 6.6 9.3 23.4 20.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 19.0 13.3 8.1 13.8 15.7 14.3 18.1 16.0
Upper Salmon 3&4 ROR 17.7 17.7 15.2 16.8 17.4 17.5 12.6 8.2 13.0 14.6 13.4 16.7 15.1
HCC Total 771.9 669.2 778.4 983.9 960.2 963.3 540.5 361.1 483.3 459.0 360.4 563.6 657.9
ROR Total 344.3 340.0 261.2 366.7 409.8 363.5 277.6 207.1 229.7 225.5 204.8 271.1 291.8
Total 1116.2 1009.2 1039.6 1350.6 1370.0 1326.8 818.1 568.2 713.0 684.5 565.2 834.7 949.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 106 2013 Integrated Resource Plan—Appendix C
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* 343.4 286.8 334.6 433.1 431.05 434.2 237.6 152.6 203.55 195.2 153 246.4 287.6
Oxbow HCC 143.6 125.3 146.6 180.1 172.7 174.9 101 69.6 92.5 88.9 69.2 103.7 122.3
Hells Canyon HCC 282.3 250.1 296.7 369.9 355.6 352.9 200.4 137.3 181.7 175.3 137.9 205.7 245.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 22.7 22.9 21.7 51.9 83.75 89.3 82.1 63.8 41.95 17.1 0 10.4 42.3
Bliss ROR 48.1 47.8 39.8 49.7 48.8 43.6 34.1 26.9 36.2 39.3 37.3 41.1 41.1
C .J. Strike ROR 62.9 62.9 54.5 63.7 63.3 53 36.4 28.1 43 50 48.9 52.8 51.6
Cascade ROR 1.5 1.5 3 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 33.3 33.3 25.1 33.0 34.7 29.3 21.9 14.9 22.7 25.3 23.4 27.5 27.0
Milner ROR 38.8 38.1 13.0 33.2 36.8 20.0 5.9 0.0 0.0 0.0 5.1 18.8 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 12.0 12.0 11.0
Swan Falls ROR 20.1 20.2 17.9 20.4 20.5 17.4 12.8 9.9 14.5 16.4 16.1 17.4 17.0
Twin Falls ROR 38.5 37.9 16.9 33.2 36.8 23.0 10.2 0.0 0.0 6.6 9.3 21.3 19.5
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.1 19.1 18.9 13.2 8.0 13.7 15.6 14.1 17.4 15.9
Upper Salmon 3&4 ROR 17.7 17.7 14.8 16.8 17.4 17.4 12.5 8.1 12.9 14.5 13.3 16.1 14.9
HCC Total 769.3 662.2 777.9 983.1 959.4 962.0 539.0 359.5 477.8 459.4 360.1 555.8 655.5
ROR Total 339.8 337.9 258.3 363.1 406.6 361.8 276.8 206.1 228.7 224.5 203.6 261.5 289.1
Total 1109.1 1000.1 1036.2 1346.2 1366.0 1323.8 815.8 565.6 706.5 683.9 563.7 817.3 944.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 342.4 286.4 336.0 432.6 430.7 433.6 237.0 152.0 200.9 195.6 153.6 242.5 286.9
Oxbow HCC 143.2 125.1 147.2 180.0 172.6 174.7 100.7 69.3 91.1 88.8 69.4 102.0 122.0
Hells Canyon HCC 281.4 249.8 297.9 369.5 355.3 352.5 199.9 136.7 178.9 175.2 138.3 202.5 244.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 22.5 22.6 21.3 51.7 83.5 89.1 82.0 63.6 41.9 16.4 0.0 8.9 42.0
Bliss ROR 47.5 47.5 39.6 49.3 48.6 43.4 34.0 26.7 36.0 39.1 36.9 40.0 40.7
C .J. Strike ROR 62.6 62.5 53.4 63.3 63.0 52.8 36.2 27.8 42.7 49.8 48.6 52.0 51.2
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 33.1 33.1 25.0 32.7 34.4 29.1 21.8 14.7 22.5 25.2 23.2 26.5 26.8
Milner ROR 38.4 37.7 12.6 32.4 36.0 19.3 5.9 0.0 0.0 0.0 5.0 16.1 17.0
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 20.0 20.1 17.6 20.3 20.4 17.3 12.7 9.8 14.4 16.3 16.0 17.2 16.8
Twin Falls ROR 38.2 37.6 16.5 32.5 36.1 22.7 10.2 0.0 0.0 6.6 9.3 19.0 19.1
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.1 18.8 13.8 19.2 19.1 18.8 13.1 7.9 13.6 15.5 14.0 16.6 15.8
Upper Salmon 3&4 ROR 17.7 17.7 14.7 16.8 17.4 17.3 12.4 8.0 12.8 14.5 13.2 15.4 14.8
HCC Total 767.0 661.3 781.1 982.1 958.5 960.8 537.6 358.0 470.9 459.6 361.3 547.0 653.8
ROR Total 337.7 335.9 255.3 360.3 403.9 359.7 276.0 204.9 227.6 223.1 202.3 250.4 286.4
Total 1104.7 997.2 1036.4 1342.4 1362.4 1320.5 813.6 562.9 698.5 682.7 563.6 797.4 940.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 107
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* 340.6 285.9 335.1 432.2 430.4 433.0 236.3 151.2 198.7 196.0 153.5 239.8 286.1
Oxbow HCC 142.4 124.9 146.9 179.8 172.5 174.4 100.5 68.9 90.0 88.8 69.3 100.8 121.6
Hells Canyon HCC 280.0 249.4 297.1 369.2 355.1 352.0 199.4 136.0 176.7 175.2 138.0 200.2 244.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 22.3 22.4 21.1 51.4 83.2 89.0 82.0 63.5 41.8 16.1 0.0 7.8 41.7
Bliss ROR 47.3 47.3 39.3 48.9 48.4 43.1 33.8 26.5 35.8 38.9 37.0 39.1 40.5
C .J. Strike ROR 62.1 62.2 53.1 63.0 62.8 52.6 36.0 27.6 42.4 49.6 48.4 50.8 50.9
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.9 32.9 25.0 32.5 34.2 29.0 21.7 14.6 22.3 25.0 23.0 25.7 26.6
Milner ROR 38.1 37.4 12.2 32.1 35.7 18.9 5.9 0.0 0.0 0.0 5.0 14.1 16.6
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 19.9 20.0 17.5 20.3 20.3 17.3 12.7 9.8 14.4 16.3 16.0 16.8 16.8
Twin Falls ROR 37.9 37.3 16.1 32.2 35.8 22.6 10.2 0.0 0.0 6.6 9.3 17.1 18.8
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 18.7 13.0 7.8 13.4 15.4 13.9 16.0 15.7
Upper Salmon 3&4 ROR 17.7 17.7 14.7 16.8 17.4 17.2 12.3 7.9 12.7 14.4 13.1 14.9 14.7
HCC Total 763.0 660.2 779.1 981.2 957.9 959.4 536.2 356.1 465.3 460.0 360.8 540.8 651.7
ROR Total 336.0 334.3 253.6 358.5 402.3 358.3 275.3 204.1 226.6 222.0 201.8 241.0 284.5
Total 1099.0 994.5 1032.7 1339.7 1360.2 1317.7 811.5 560.2 691.8 682.0 562.6 781.8 936.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 338.7 285.6 334.1 431.3 430.1 428.0 235.7 150.4 196.5 196.5 153.9 236.7 284.8
Oxbow HCC 141.7 124.8 146.4 179.4 172.3 172.5 100.2 68.6 88.8 88.8 69.4 99.5 121.0
Hells Canyon HCC 278.5 249.1 296.3 368.5 354.8 348.2 198.9 135.3 174.4 175.2 138.2 197.6 242.9
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 22.1 22.2 20.8 51.1 82.8 88.8 82.0 63.4 41.7 17.0 0.0 6.8 41.6
Bliss ROR 47.0 47.1 39.1 48.5 48.2 42.6 33.6 26.3 35.7 38.8 36.3 38.2 40.1
C .J. Strike ROR 61.3 61.9 52.8 62.6 62.7 52.4 35.8 27.4 42.2 49.4 48.0 50.0 50.5
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.7 32.7 24.8 32.3 34.0 28.1 21.5 14.4 22.1 24.9 22.9 24.9 26.3
Milner ROR 37.8 37.1 12.2 31.7 35.4 18.7 5.9 0.0 0.0 0.0 4.6 12.4 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 12.0 12.0 11.0
Swan Falls ROR 19.7 19.9 17.4 20.2 20.2 17.2 12.6 9.7 14.3 16.2 15.9 16.5 16.7
Twin Falls ROR 37.7 37.0 15.7 31.9 35.6 22.5 10.2 0.0 0.0 6.6 9.2 15.5 18.5
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 18.0 12.9 7.6 13.3 15.3 13.7 15.4 15.5
Upper Salmon 3&4 ROR 17.7 17.7 14.6 16.8 17.4 16.6 12.2 7.8 12.6 14.3 12.9 14.4 14.6
HCC Total 758.9 659.5 776.8 979.2 957.2 948.7 534.8 354.3 459.6 460.5 361.5 533.8 648.7
ROR Total 333.8 332.7 252.0 356.4 400.9 354.8 274.4 203.0 225.7 222.2 199.6 232.8 282.4
Total 1092.7 992.2 1028.8 1335.6 1358.0 1303.5 809.2 557.3 685.3 682.7 561.1 766.6 931.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 108 2013 Integrated Resource Plan—Appendix C
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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.7 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.2 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.3 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.6 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.1 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.2 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 109
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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.6 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.1 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.2 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.6 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.1 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.2 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 110 2013 Integrated Resource Plan—Appendix C
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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.6 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.1 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.2 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 50th Percentile Water, 50th 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* 333.8 285.1 333.1 430.4 421.8 423.2 235.1 149.9 194.3 196.8 154.0 234.0 282.6
Oxbow HCC 139.7 124.6 146.0 187.2 169.1 170.6 100.0 68.3 87.6 88.8 69.3 98.3 120.8
Hells Canyon HCC 274.6 248.8 295.5 378.4 348.5 344.5 198.4 134.8 172.1 175.2 138.1 195.3 242.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 20.6 21.9 20.6 50.0 82.6 88.7 81.7 63.3 41.6 16.1 0.0 5.6 41.1
Bliss ROR 46.8 46.8 38.8 48.2 48.0 42.5 33.5 26.2 35.5 38.6 36.2 37.3 39.9
C .J. Strike ROR 61.0 61.6 52.4 62.1 62.6 52.1 35.6 27.1 41.9 49.2 47.9 49.5 50.3
Cascade ROR 1.5 1.5 3.0 5.8 5.5 11.1 10.2 13.3 8.8 1.9 1.4 1.4 5.5
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 32.2 32.5 24.6 32.0 33.8 27.9 21.4 14.3 22.0 24.8 22.7 24.1 26.0
Milner ROR 35.7 36.6 11.7 31.3 35.1 18.2 5.9 0.0 0.0 0.0 4.6 10.5 15.8
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 19.6 19.8 17.3 20.0 20.2 17.1 12.5 9.6 14.2 16.2 15.8 16.3 16.6
Twin Falls ROR 35.7 36.6 15.3 31.6 35.3 21.8 10.2 0.0 0.0 6.6 9.2 13.7 18.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 19.2 18.8 13.8 19.2 19.1 17.8 12.8 7.5 13.2 15.2 13.6 14.8 15.4
Upper Salmon 3&4 ROR 17.7 17.7 14.4 16.8 17.4 16.5 12.1 7.7 12.5 14.2 12.8 13.8 14.5
HCC Total 748.1 658.5 774.6 996.0 939.3 938.3 533.5 353.0 453.9 460.8 361.4 527.6 645.4
ROR Total 327.1 330.6 249.7 353.3 399.5 352.5 273.4 202.1 224.7 220.6 198.9 224.3 279.7
Total 1075.2 989.1 1024.3 1349.3 1338.8 1290.8 806.9 555.1 678.6 681.4 560.3 751.9 925.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 111
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013 aMW
Brownlee HCC* 256.5 264.8 259.1 301.5 390.1 316.6 228.7 162.7 184.9 177.2 156.2 208.7 242.2
Oxbow HCC 108.2 113.0 110.6 123.5 157.5 127.8 96.9 74.3 84.9 79.2 69.5 87.3 102.7
Hells Canyon HCC 214.2 225.5 225.7 251.2 320.0 258.2 191.3 145.8 166.4 156.2 138.1 173.1 205.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 5.7 11.1 33.8 72.6 88.6 83.0 64.1 34.1 11.6 0.0 0.0 33.7
Bliss ROR 38.3 39.7 37.4 37.2 42.1 40.8 34.8 31.5 37.1 39.3 37.4 37.4 37.8
C .J. Strike ROR 49.9 52.8 49.0 49.9 52.7 47.0 36.8 33.9 44.3 50.1 48.5 48.5 47.0
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.9 25.0 22.2 23.0 28.5 28.3 22.7 19.1 23.6 25.5 24.0 23.8 24.1
Milner ROR 8.9 10.6 5.2 3.7 17.0 17.0 5.9 6.7 0.0 0.0 3.6 6.2 7.1
Shoshone Falls ROR 12.0 12.0 12.0 11.3 12.0 12.0 12.0 12.0 6.7 10.5 12.0 12.0 11.4
Swan Falls ROR 16.3 17.4 16.2 16.3 17.4 15.5 12.9 11.9 14.9 16.4 16.0 16.0 15.6
Twin Falls ROR 11.5 13.7 8.6 7.3 19.9 20.6 10.2 11.5 0.0 6.6 8.3 9.5 10.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.7 15.7 13.6 14.2 18.5 18.2 13.8 11.2 14.4 15.8 14.6 14.5 14.9
Upper Salmon 3&4 ROR 13.7 14.6 12.8 13.4 17.1 16.8 13 10.8 13.5 14.7 13.7 13.6 14.0
HCC Total 578.9 603.3 595.4 676.2 867.6 702.6 516.9 382.8 436.1 412.6 363.8 469.1 550.4
ROR Total 215.8 233.5 215.2 235.6 327.8 336.9 278.2 251.1 224.1 219.3 202.1 208.2 245.7
Total 794.7 836.8 810.6 911.8 1195.4 1039.5 795.1 633.9 660.2 631.9 565.9 677.3 796.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource Type 1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014 aMW
Brownlee HCC* 254.6 264.1 258.4 300.2 389.8 315.8 228.2 162.1 184.3 176.1 156.3 207.3 241.4
Oxbow HCC 107.4 112.7 110.2 123.0 157.3 127.5 96.7 74.0 84.6 78.6 69.6 86.7 102.4
Hells Canyon HCC 212.7 224.9 225.1 250.2 319.7 257.5 190.8 145.3 165.8 155.2 138.1 171.9 204.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0 0 10.4 32.8 72.6 88.5 83.1 64 34.05 11.6 0 0 33.1
Bliss ROR 38.2 39.4 36.8 36.1 42 40.6 34.7 31.4 36.9 39.2 37.2 37.1 37.5
C .J. Strike ROR 49.8 51.8 48.7 48.9 52.6 46.8 36.6 33.7 44.1 49.8 48.3 48 46.6
Cascade ROR 1.5 1.5 1.3 1.2 2.05 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.8 24.2 22.2 22.6 28.4 28.2 22.5 18.9 23.4 25.4 23.9 23.6 23.9
Milner ROR 8.9 8.8 4.8 2.3 17 17 5.9 6.7 0 0 3.6 6.2 6.8
Shoshone Falls ROR 12 12 12 10 12 12 12 12 6.7 10.5 12 12 11.3
Swan Falls ROR 16.2 17.1 16.1 16.2 17.3 15.5 12.8 11.8 14.8 16.4 15.9 15.9 15.5
Twin Falls ROR 11.5 12.1 8.3 6.2 19.9 20.6 10.2 11.5 0 6.6 8.3 9.5 10.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.6 15.0 13.6 14.0 18.5 18.1 13.7 11.1 14.3 15.7 14.5 14.4 14.8
Upper Salmon 3&4 ROR 13.7 14.1 12.8 13.1 17.0 16.7 12.9 10.7 13.4 14.6 13.6 13.5 13.8
HCC Total 574.7 601.7 593.7 673.4 866.8 700.8 515.7 381.4 434.6 409.9 364.0 465.9 548.5
ROR Total 215.3 220.8 212.8 227.7 327.3 336.1 277.5 250.2 223.2 218.6 201.3 206.9 243.1
Total 790.0 822.5 806.5 901.1 1194.1 1036.9 793.2 631.6 657.8 628.5 565.3 672.8 791.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 112 2013 Integrated Resource Plan—Appendix C
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* 257.8 271.6 260.5 319.5 390.6 317.6 228.2 162.0 184.0 179.2 155.8 213.0 245.0
Oxbow HCC 108.8 115.9 111.1 130.7 157.6 128.2 96.7 74.0 84.4 80.2 69.5 89.1 103.9
Hells Canyon HCC 215.3 231.1 226.8 265.1 320.3 259.0 190.9 145.2 165.6 158.1 137.9 176.7 207.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 9.9 13.5 37.1 72.7 89.4 83.2 65.2 34.9 13.4 0.0 0.0 34.9
Bliss ROR 38.4 40.8 37.3 38.8 42.5 40.7 34.6 31.3 36.8 39.4 37.6 37.4 38.0
C .J. Strike ROR 50.1 54.5 48.3 52.7 52.8 47.1 36.6 33.6 44.0 50.1 48.5 49.1 47.3
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 24.4 27.0 22.1 24.9 28.6 28.4 22.5 18.8 23.3 25.6 24.1 23.8 24.5
Milner ROR 8.9 17.1 4.0 8.5 18.2 18.2 5.9 6.7 0.0 0.0 3.6 6.2 8.1
Shoshone Falls ROR 12.0 12.0 11.9 12.0 12.0 12.0 12.0 12.0 6.7 10.5 12.0 12.0 11.4
Swan Falls ROR 16.4 17.7 16.0 17.3 17.4 15.7 12.8 11.8 14.8 16.4 15.9 16.1 15.7
Twin Falls ROR 11.7 19.5 7.8 11.3 20.6 21.7 10.2 11.5 0.0 6.6 8.3 9.5 11.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 15.0 17.2 13.5 15.8 18.6 18.2 13.7 11.0 14.2 15.8 14.7 14.5 15.2
Upper Salmon 3&4 ROR 14.0 16.0 12.8 14.7 17.1 16.8 12.9 10.6 13.4 14.7 13.8 13.6 14.2
HCC Total 581.9 618.6 598.4 715.3 868.5 704.8 515.8 381.2 433.9 417.5 363.2 478.8 556.5
ROR Total 217.5 258.0 214.3 258.6 330.5 340.3 277.5 250.9 223.7 221.3 202.5 208.9 250.3
Total 799.4 876.6 812.7 973.9 1199.0 1045.1 793.3 632.1 657.6 638.8 565.7 687.7 806.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 257.4 270.8 260.8 318.1 392.0 317.1 227.6 149.1 183.3 178.6 155.9 216.8 244.0
Oxbow HCC 108.6 115.6 111.3 130.1 158.2 128.0 96.5 67.9 84.1 79.9 69.6 90.8 103.4
Hells Canyon HCC 214.9 230.5 227.1 264.0 321.5 258.5 190.4 133.7 164.9 157.6 138.1 179.9 206.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 14.0 13.3 38.8 72.7 89.4 83.1 61.2 36.0 13.6 0.0 0.0 35.2
Bliss ROR 38.5 42.4 36.4 38.9 42.4 40.6 34.5 27.6 36.6 39.2 37.6 37.3 37.7
C .J. Strike ROR 49.9 54.8 47.7 52.4 52.7 47.0 36.4 28.8 43.7 49.9 48.4 48.9 46.7
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 24.3 29.1 22.2 25.1 28.5 28.2 22.4 15.6 23.2 25.5 23.9 23.8 24.3
Milner ROR 9.0 24.2 4.6 8.7 18.2 18.2 5.9 0.0 0.0 0.0 3.6 6.2 8.2
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 16.3 17.9 15.8 17.3 17.4 15.6 12.8 10.1 14.7 16.4 15.9 16.0 15.5
Twin Falls ROR 12.0 25.6 8.2 11.4 20.6 21.7 10.2 0.0 0.0 6.6 8.3 9.5 11.2
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.9 18.9 13.6 15.9 18.5 18.1 13.5 8.5 14.1 15.7 14.6 14.5 15.1
Upper Salmon 3&4 ROR 14.0 17.4 12.8 14.8 17.1 16.7 12.8 8.5 13.3 14.6 13.7 13.6 14.1
HCC Total 580.9 616.9 599.2 712.2 871.7 703.6 514.5 350.7 432.3 416.1 363.6 487.5 554.1
ROR Total 217.5 282.6 213.7 260.8 330.1 339.6 276.7 205.6 223.9 220.8 202.0 208.5 248.5
Total 798.4 899.5 812.9 973.0 1201.8 1043.2 791.2 556.3 656.1 636.9 565.6 696.0 802.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 113
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* 257.0 270.2 259.3 312.5 389.8 316.5 227.1 148.6 182.7 177.6 156.1 216.4 242.8
Oxbow HCC 108.4 115.3 110.6 127.9 157.4 127.8 96.3 67.6 83.9 79.4 69.6 90.6 102.9
Hells Canyon HCC 214.6 230.0 225.8 259.7 319.8 258.1 190.0 133.2 164.5 156.7 138.2 179.5 205.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 12.8 13.2 37.3 72.7 89.3 83.0 61.2 36.0 13.6 0.0 0.0 34.9
Bliss ROR 38.5 41.7 36.0 37.8 42.4 40.4 34.4 27.4 36.4 39.1 37.4 37.2 37.4
C .J. Strike ROR 49.8 54.7 47.4 52.0 52.6 46.8 36.2 28.6 43.5 49.8 48.1 48.8 46.5
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 24.2 28.5 21.9 24.1 28.5 28.1 22.3 15.5 23 25.4 23.8 23.7 24.1
Milner ROR 8.9 22.2 2.4 6.2 18.2 18.2 5.9 0 0 0 3.6 6.2 7.7
Shoshone Falls ROR 12 12 10.2 12 12 12 12 6.9 6.7 10.5 12 12 10.9
Swan Falls ROR 16.3 17.9 15.7 17.1 17.3 15.5 12.7 10.1 14.6 16.3 15.9 16 15.5
Twin Falls ROR 11.7 23.8 6.4 9.5 20.6 21.4 10.2 0 0 6.6 8.4 9.5 10.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.9 18.4 13.4 15.1 18.5 18.0 13.5 8.4 14.0 15.6 14.5 14.4 14.9
Upper Salmon 3&4 ROR 13.9 16.9 12.6 14.1 17.0 16.6 12.7 8.4 13.2 14.6 13.6 13.5 13.9
HCC Total 580.0 615.5 595.7 700.1 867.0 702.4 513.4 349.4 431.0 413.7 363.9 486.5 551.6
ROR Total 216.8 275.2 206.3 250.7 329.8 338.4 276.0 204.9 222.9 220.3 201.3 208.0 245.9
Total 796.8 890.7 802.0 950.8 1196.8 1040.8 789.4 554.3 653.9 634.0 565.2 694.5 797.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 256.6 265.8 255.9 311.9 389.4 312.7 226.6 148.0 182.2 176.2 156.1 213.6 241.2
Oxbow HCC 108.3 113.4 109.2 127.7 157.2 126.3 96.0 67.4 83.6 78.7 69.6 89.4 102.2
Hells Canyon HCC 214.3 226.3 223.0 259.2 319.5 255.2 189.5 132.7 163.9 155.4 138.1 177.2 204.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0 6 13 37.3 73.35 89.3 83.1 61.1 35.8 13.4 0 0 34.4
Bliss ROR 38 39.7 35.9 37.6 42.1 40.3 34.3 27.2 36.2 39 37.3 37 37.1
C .J. Strike ROR 49.7 52.5 47.3 51.9 52.5 46.6 36.1 28.4 43.3 49.5 47.9 48.6 46.2
Cascade ROR 1.5 1.5 1.3 1.2 2.05 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.9 24.6 21.9 23.9 28.4 28 22.1 15.3 22.9 25.2 23.7 23.5 23.6
Milner ROR 8.9 11 2.4 6.4 18.2 18.2 5.9 0 0 0 3.6 6.2 6.7
Shoshone Falls ROR 12 12 10.2 12 12 12 12 6.9 6.7 10.5 12 12 10.9
Swan Falls ROR 16.3 17.3 15.8 17 17.3 15.4 12.7 10 14.6 16.3 15.8 15.9 15.4
Twin Falls ROR 11.5 14.1 6.4 9.2 20.6 21 10.2 0 0 6.6 8.4 9.5 9.8
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.7 15.4 13.3 15.0 18.4 17.9 13.4 8.3 13.9 15.5 14.4 14.3 14.5
Upper Salmon 3&4 ROR 13.8 14.4 12.6 14.0 17.0 16.5 12.6 8.3 13.1 14.5 13.5 13.4 13.6
HCC Total 579.2 605.5 588.1 698.8 866.1 694.2 512.1 348.1 429.6 410.3 363.8 480.2 548.0
ROR Total 215.4 233.3 205.9 249.8 329.9 337.3 275.5 203.9 222.1 219.3 200.6 207.1 241.7
Total 794.6 838.8 794.0 948.6 1196.0 1031.5 787.6 552.0 651.7 629.6 564.4 687.3 789.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 114 2013 Integrated Resource Plan—Appendix C
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* 256.2 264.3 255.9 310.0 389.1 310.8 226.1 147.4 181.6 167.5 156.0 211.0 239.7
Oxbow HCC 108.1 112.8 109.2 126.9 157.1 125.5 95.8 67.1 83.3 78.0 69.4 88.3 101.8
Hells Canyon HCC 214.0 225.0 223.0 257.8 319.2 253.7 189.1 132.2 163.4 153.5 137.9 175.0 203.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0 0 12.5 36.6 73.3 89.2 83.1 60.6 35.2 13.7 0 0 33.7
Bliss ROR 37.9 39.3 35.8 37.2 42 40.2 34.2 27.1 36.1 38.8 37 36.9 36.9
C .J. Strike ROR 49.6 51.5 47.2 51.5 52.4 46.4 35.9 28.1 43 49.3 47.7 48.5 45.9
Cascade ROR 1.5 1.5 1.3 1.2 2.05 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.8 24.3 21.6 22.7 28.3 27.9 22.0 15.2 22.8 25.1 23.5 23.5 23.4
Milner ROR 8.9 10.1 0.0 4.7 18.2 18.2 5.9 0.0 0.0 0.0 3.6 6.2 6.3
Shoshone Falls ROR 12.0 12.0 9.0 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.8
Swan Falls ROR 16.2 17.0 15.6 16.8 17.3 15.4 12.7 9.9 14.5 16.2 15.7 15.9 15.3
Twin Falls ROR 11.5 13.3 5.4 8.5 20.6 21.0 10.2 0.0 0.0 6.6 8.4 9.5 9.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.6 15.1 13.1 14.0 18.3 17.8 13.3 8.2 13.8 15.4 14.2 14.3 14.3
Upper Salmon 3&4 ROR 13.7 14.1 12.4 13.2 16.9 16.5 12.6 8.2 13.0 14.4 13.4 13.4 13.5
HCC Total 578.3 602.1 588.1 694.7 865.4 690.0 511.0 346.7 428.2 399.0 363.3 474.3 545.1
ROR Total 214.8 223.0 199.7 242.7 329.3 336.7 275.0 202.6 220.7 218.8 199.5 206.9 239.1
Total 793.1 825.1 787.8 937.4 1194.7 1026.7 786.0 549.3 648.9 617.8 562.8 681.2 784.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 255.7 262.7 255.8 308.3 388.7 309.5 225.5 146.8 180.9 166.0 156.4 208.4 238.7
Oxbow HCC 107.9 112.1 109.1 126.2 156.9 125.0 95.6 66.8 83.0 77.2 69.6 87.2 101.4
Hells Canyon HCC 213.6 223.7 222.9 256.5 319.0 252.8 188.6 131.7 162.8 152.0 138.1 172.9 202.9
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 11.6 36.9 73.3 89.1 83.1 60.5 35.2 13.7 0.0 0.0 33.6
Bliss ROR 37.7 39.0 35.3 36.1 41.9 40.0 34.0 26.9 35.9 38.6 36.6 36.7 36.6
C .J. Strike ROR 49.4 51.3 46.8 50.1 52.3 46.2 35.7 27.9 42.8 49.1 47.4 48.2 45.6
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.7 23.9 21.5 22.1 28.2 27.8 21.9 15.0 22.7 25.0 23.4 23.3 23.2
Milner ROR 8.9 9.1 0.0 3.6 18.2 17.9 5.9 0.0 0.0 0.0 3.6 6.2 6.1
Shoshone Falls ROR 12.0 12.0 9.1 11.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.7
Swan Falls ROR 16.2 17.0 15.5 16.5 17.3 15.3 12.6 9.9 14.5 16.2 15.7 15.8 15.2
Twin Falls ROR 11.5 12.6 5.4 7.7 20.4 21.0 10.2 0.0 0.0 6.6 8.4 9.5 9.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.5 14.8 13.1 13.5 18.3 17.7 13.2 8.1 13.7 15.3 14.1 14.2 14.2
Upper Salmon 3&4 ROR 13.6 13.9 12.4 12.8 16.9 16.4 12.5 8.1 12.9 14.3 13.3 13.3 13.4
HCC Total 577.2 598.5 587.8 691.0 864.6 687.3 509.7 345.3 426.6 395.2 364.1 468.5 543.0
ROR Total 214.1 219.9 197.8 236.5 328.8 335.5 274.2 201.7 219.9 218.1 198.5 205.9 237.6
Total 791.3 818.4 785.6 927.5 1193.4 1022.8 783.9 547.0 646.5 613.3 562.6 674.4 780.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 115
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* 255.2 260.1 255.7 306.4 388.4 307.9 224.8 146.1 180.1 165.9 156.1 212.9 238.3
Oxbow HCC 107.7 111.0 109.1 125.5 156.8 124.4 95.3 66.5 82.6 77.1 69.5 89.1 101.2
Hells Canyon HCC 213.1 221.6 222.9 255.0 318.7 251.5 188.1 131.1 162.1 151.9 138.0 176.6 202.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 10.3 35.6 73.3 88.9 83.0 60.4 35.0 13.7 0.0 0.0 33.3
Bliss ROR 37.6 38.9 35.1 36.8 41.8 39.9 33.9 26.7 35.7 38.5 36.4 36.5 36.5
C .J. Strike ROR 49.2 51.2 46.7 49.9 52.2 45.7 35.5 27.6 42.5 48.9 47.2 47.8 45.4
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.3 23.7 21.4 22.5 28.1 27.7 21.7 14.8 22.5 24.8 23.1 23.2 23.1
Milner ROR 8.9 9.1 0.0 4.6 17.4 17.1 5.9 0.0 0.0 0.0 3.6 6.2 6.1
Shoshone Falls ROR 12.0 12.0 9.1 12.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.8
Swan Falls ROR 16.0 16.9 15.5 16.4 17.2 15.2 12.6 9.8 14.4 16.1 15.6 15.7 15.1
Twin Falls ROR 11.5 12.6 5.4 8.1 20.1 20.6 10.2 0.0 0.0 6.6 8.4 9.5 9.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.2 14.7 13.0 13.9 18.2 17.6 13.1 8.0 13.6 15.2 13.9 14.1 14.1
Upper Salmon 3&4 ROR 13.4 13.8 12.3 13.1 16.8 16.3 12.4 8.0 12.8 14.2 13.1 13.2 13.3
HCC Total 576.0 592.7 587.7 686.9 863.9 683.8 508.2 343.7 424.8 394.9 363.6 478.6 542.1
ROR Total 212.7 219.2 195.9 238.4 327.1 333.1 273.4 200.6 218.7 217.3 197.3 204.9 236.6
Total 788.7 811.9 783.6 925.3 1191.0 1016.9 781.6 544.3 643.5 612.2 560.9 683.5 778.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 254.7 259.7 255.7 305.5 388.0 307.1 224.2 145.5 179.5 164.3 156.2 209.3 237.5
Oxbow HCC 107.4 110.8 109.1 125.1 156.7 124.1 95.0 66.2 82.3 76.3 69.4 87.6 100.8
Hells Canyon HCC 212.7 221.2 222.8 254.3 318.4 250.9 187.5 130.5 161.5 150.4 137.9 173.6 201.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0 0 10.1 35.6 73.3 88.9 83.1 60.3 34.85 13.6 0 0 33.3
Bliss ROR 37.5 38.6 35 36.6 41.7 39.7 33.7 26.5 35.5 38.3 36.2 36.4 36.3
C .J. Strike ROR 49.1 50.7 46.6 49.6 52 45.5 35.2 27.4 42.3 48.7 46.9 47.6 45.1
Cascade ROR 1.5 1.5 1.3 1.2 2.05 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.1 23.6 21.3 22.3 28.1 27.5 21.6 14.7 22.3 24.6 22.9 23.1 22.9
Milner ROR 8.9 9.1 0.0 2.7 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.9
Shoshone Falls ROR 12.0 12.0 8.6 11.0 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.6
Swan Falls ROR 16.0 16.8 15.5 16.3 17.2 15.4 12.5 9.7 14.3 16.0 15.5 15.7 15.1
Twin Falls ROR 11.5 12.6 4.8 7.1 20.1 20.6 10.2 0.0 0.0 6.6 8.4 9.5 9.3
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.1 14.6 12.9 13.7 18.2 17.5 12.9 7.8 13.4 15.1 13.8 14.0 14.0
Upper Salmon 3&4 ROR 13.2 13.7 12.2 12.9 16.8 16.2 12.3 7.9 12.7 14.1 13.0 13.1 13.2
HCC Total 574.8 591.7 587.6 684.9 863.1 682.1 506.7 342.2 423.2 391.0 363.5 470.5 540.1
ROR Total 212.0 218.0 194.1 233.3 326.4 332.4 272.5 199.6 217.6 216.3 196.3 204.3 235.2
Total 786.8 809.7 781.7 918.2 1189.5 1014.5 779.2 541.8 640.8 607.3 559.8 674.8 775.3
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 116 2013 Integrated Resource Plan—Appendix C
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* 254.2 259.4 255.6 304.3 387.6 306.6 223.5 144.8 178.9 162.6 156.6 205.8 236.7
Oxbow HCC 107.2 110.7 109.0 124.6 156.5 123.9 94.7 65.9 82.1 75.4 69.5 86.1 100.5
Hells Canyon HCC 212.3 221.0 222.7 253.3 318.1 250.5 187.0 129.9 161.0 148.7 138.1 170.7 201.1
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 9.1 36.0 73.3 88.9 83.1 60.3 34.8 13.6 0.0 0.0 33.3
Bliss ROR 37.3 37.6 34.9 35.8 41.6 39.6 33.5 26.3 35.3 38.1 36.0 36.2 36.0
C .J. Strike ROR 48.6 49.7 46.5 49.3 51.9 45.3 35.0 27.1 42.0 48.5 46.6 46.8 44.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 23.0 23.5 21.3 21.8 28.0 27.3 21.4 14.5 22.1 24.5 22.7 22.8 22.7
Milner ROR 8.9 8.7 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.6
Shoshone Falls ROR 12.0 12.0 8.6 8.1 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.4
Swan Falls ROR 15.9 16.3 15.3 16.3 17.2 15.3 12.4 9.7 14.2 16.0 15.4 15.5 15.0
Twin Falls ROR 11.5 11.8 4.8 4.4 20.1 20.6 10.2 0.0 0.0 6.6 8.4 9.5 9.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 14.0 14.5 12.9 13.3 18.1 17.4 12.8 7.7 13.3 14.9 13.6 13.8 13.9
Upper Salmon 3&4 ROR 13.2 13.6 12.2 12.6 16.7 16.1 12.2 7.8 12.6 14.0 12.8 13.0 13.1
HCC Total 573.7 591.1 587.3 682.2 862.2 681.0 505.2 340.6 421.9 386.7 364.2 462.6 538.2
ROR Total 211.0 214.0 192.7 223.1 325.9 331.6 271.6 198.7 216.6 215.5 195.1 202.5 233.2
Total 784.7 805.1 780.0 905.3 1188.1 1012.6 776.8 539.3 638.4 602.2 559.3 665.1 771.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 253.7 259.0 255.5 302.0 387.2 305.9 222.9 144.2 178.6 161.3 156.7 203.7 235.9
Oxbow HCC 107.0 110.5 109.0 123.7 156.3 123.6 94.5 65.6 81.9 74.7 69.5 85.2 100.1
Hells Canyon HCC 211.9 220.6 222.7 251.6 317.8 250.0 186.5 129.3 160.7 147.4 138.0 168.9 200.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 8.0 35.6 73.3 88.9 83.1 60.2 34.8 13.5 0.0 0.0 33.1
Bliss ROR 37.2 37.5 34.8 35.5 41.5 39.4 33.4 26.1 35.1 38.0 35.8 35.9 35.9
C .J. Strike ROR 47.8 49.4 46.5 48.2 51.8 45.2 34.8 26.9 41.7 48.3 46.4 46.6 44.5
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.8 23.4 21.0 20.9 27.9 27.2 21.3 14.3 22.0 24.4 22.5 22.6 22.5
Milner ROR 8.2 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.5
Shoshone Falls ROR 12.0 12.0 8.5 4.8 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.7 16.2 15.3 16.0 17.1 15.3 12.4 9.6 14.1 15.9 15.4 15.5 14.9
Twin Falls ROR 11.5 11.2 4.8 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.8 14.4 12.7 12.7 18.0 17.2 12.7 7.6 13.2 14.9 13.5 13.6 13.7
Upper Salmon 3&4 ROR 13.0 13.5 12.0 12.0 16.7 16.0 12.1 7.7 12.5 13.9 12.7 12.8 12.9
HCC Total 572.6 590.1 587.2 677.3 861.3 679.5 503.9 339.1 421.1 383.4 364.2 457.8 536.5
ROR Total 208.6 212.2 190.7 211.2 325.2 330.9 271.0 197.7 215.6 214.8 194.3 201.4 231.1
Total 781.2 802.3 777.9 888.5 1186.5 1010.4 774.9 536.8 636.7 598.2 558.5 659.2 767.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 117
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* 253.2 258.4 255.4 297.3 386.9 305.3 222.2 143.5 178.1 159.6 156.9 203.1 235.0
Oxbow HCC 106.8 110.3 109.0 121.9 156.2 123.4 94.2 65.3 81.7 73.8 69.6 84.9 99.8
Hells Canyon HCC 211.5 220.2 222.6 247.9 317.5 249.6 185.9 128.8 160.2 145.7 138.1 168.5 199.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 8.0 35.5 73.3 88.8 83.0 60.2 34.8 13.5 0.0 0.0 33.1
Bliss ROR 36.7 37.4 34.7 34.8 41.4 39.3 33.2 25.9 34.9 37.8 35.6 35.8 35.6
C .J. Strike ROR 47.6 49.3 46.2 48.0 51.7 45.0 34.6 26.7 41.4 48.0 46.1 46.2 44.2
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.7 23.3 21 20.7 27.8 27 21.2 14.2 21.8 24.3 22.4 22.5 22.4
Milner ROR 8.2 8.3 0 0 17 17 5.9 0 0 0 3.6 6.2 5.5
Shoshone Falls ROR 12 12 8.5 4.8 12 12 12 6.9 6.7 10.5 12 12 10.1
Swan Falls ROR 15.6 16.2 15.3 15.9 17.1 15.2 12.3 9.5 14.1 15.9 15.3 15.4 14.8
Twin Falls ROR 11.5 11.2 4.8 0 19.9 20.6 10.2 0 0 6.6 8.4 9.5 8.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.8 14.3 12.6 12.5 18.0 17.2 12.6 7.5 13.0 14.8 13.4 13.5 13.6
Upper Salmon 3&4 ROR 13.0 13.5 12.0 11.9 16.6 15.9 12.0 7.6 12.4 13.9 12.6 12.7 12.8
HCC Total 571.5 588.9 587.0 667.1 860.6 678.3 502.3 337.6 419.9 379.1 364.6 456.5 534.5
ROR Total 207.7 211.8 190.2 209.6 324.8 330.1 270.1 196.9 214.6 214.1 193.4 200.5 230.3
Total 779.2 800.7 777.2 876.7 1185.4 1008.4 772.4 534.5 634.5 593.2 558.0 657.0 764.8
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 252.3 257.9 255.2 297.0 386.5 304.7 221.6 142.9 177.5 157.9 157.0 203.0 234.5
Oxbow HCC 106.4 110.1 108.9 121.7 156.1 123.1 93.9 65.0 81.4 73.0 69.5 84.9 99.5
Hells Canyon HCC 210.8 219.8 222.4 247.7 317.3 249.1 185.4 128.2 159.7 144.1 138.1 168.4 199.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.8 83.0 60.1 34.8 13.5 0.0 0.0 33.0
Bliss ROR 36.5 37.3 34.6 34.7 41.3 39.2 33.0 25.7 34.7 37.7 35.4 35.6 35.5
C .J. Strike ROR 47.4 49.1 45.9 47.9 51.6 44.8 34.4 26.4 41.2 47.8 45.9 46.1 44.0
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.5 23.2 20.9 20.7 27.8 26.9 21.0 14.0 21.6 24.2 22.2 22.3 22.3
Milner ROR 7.6 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.5
Shoshone Falls ROR 12.0 12.0 8.5 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.6 16.1 15.2 15.8 17.1 15.2 12.2 9.4 14.1 15.8 15.2 15.3 14.8
Twin Falls ROR 10.6 11.2 4.8 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.5
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.6 14.3 12.6 12.4 17.9 17.0 12.5 7.3 12.9 14.7 13.2 13.4 13.5
Upper Salmon 3&4 ROR 12.8 13.4 12.0 11.8 16.6 15.8 11.9 7.5 12.2 13.8 12.5 12.7 12.8
HCC Total 569.5 587.8 586.5 666.4 859.9 676.9 500.9 336.1 418.6 375.0 364.6 456.3 533.2
ROR Total 205.2 211.2 188.6 209.0 324.5 329.4 269.2 195.7 213.7 213.4 192.4 199.8 229.3
Total 774.7 799.0 775.1 875.4 1184.4 1006.3 770.1 531.8 632.3 588.4 557.0 656.1 762.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 118 2013 Integrated Resource Plan—Appendix C
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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17.0 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 119
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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17.0 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17.0 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 120 2013 Integrated Resource Plan—Appendix C
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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17.0 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 70th Percentile Water, 70th 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* 248.9 257.4 255.0 296.6 386.1 304.1 221.0 142.3 176.9 156.8 157.1 202.4 233.7
Oxbow HCC 105.0 109.8 108.8 121.5 155.9 122.9 93.7 64.7 81.1 72.4 69.5 84.6 99.2
Hells Canyon HCC 208.0 219.3 222.3 247.3 316.9 248.6 184.9 127.6 159.2 143.1 138.1 167.9 198.6
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 35.5 73.3 88.7 82.9 60.0 34.7 13.5 0.0 0.0 33.0
Bliss ROR 36.3 37.0 34.5 34.6 41.0 38.7 32.9 25.5 34.6 37.5 35.2 35.5 35.3
C .J. Strike ROR 47.1 49.0 45.6 47.5 51.5 44.5 34.2 26.2 41.0 47.6 45.6 45.9 43.8
Cascade ROR 1.5 1.5 1.3 1.2 2.1 5.3 7.6 12.2 7.3 1.5 1.3 1.4 3.7
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 23.1 20.8 20.6 27.7 26.8 20.9 13.9 21.5 24.0 22.1 22.2 22.2
Milner ROR 6.9 8.3 0.0 0.0 17.0 17.0 5.9 0.0 0.0 0.0 3.6 6.2 5.4
Shoshone Falls ROR 12.0 12.0 8.0 4.7 12.0 12.0 12.0 6.9 6.7 10.5 12.0 12.0 10.1
Swan Falls ROR 15.5 16.1 15.4 15.8 17.0 15.1 12.2 9.3 14.0 15.7 15.4 15.3 14.7
Twin Falls ROR 10.0 11.2 4.4 0.0 19.9 20.6 10.2 0.0 0.0 6.6 8.4 9.5 8.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 14.2 12.5 12.4 17.9 17.0 12.4 7.2 12.8 14.6 13.1 13.3 13.4
Upper Salmon 3&4 ROR 12.7 13.3 11.9 11.8 16.5 15.7 11.8 7.4 12.1 13.7 12.4 12.6 12.7
HCC Total 561.9 586.5 586.1 665.4 858.9 675.6 499.6 334.6 417.1 372.3 364.7 454.9 531.5
ROR Total 203.0 210.5 187.2 208.4 323.8 328.2 268.5 194.8 213.0 212.5 191.8 199.2 228.4
Total 764.9 797.0 773.3 873.8 1182.7 1003.8 768.1 529.4 630.1 584.8 556.5 654.1 759.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 121
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2013 2/2013 3/2013 4/2013 5/2013 6/2013 7/2013 8/2013 9/2013 10/2013 11/2013 12/2013 aMW
Brownlee HCC* 200.7 199.7 244.5 251.3 294.0 213.0 214.2 150.3 152.4 156.4 158.7 194.2 202.5
Oxbow HCC 83.5 82.9 101.7 104.6 119.0 88.3 90.4 68.4 70.1 71.0 69.7 80.9 85.9
Hells Canyon HCC 165.2 165.0 205.8 212.3 241.6 177.7 177.7 134.2 137.5 140.0 138.1 159.9 171.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 0.0 29.7 71.0 86.4 83.8 56.4 25.7 9.1 0.0 0.0 30.2
Bliss ROR 35.3 35.3 33.9 32.7 38.8 37.6 33.7 30.4 35.3 37.8 36.1 35.8 35.2
C .J. Strike ROR 44.7 44.3 43.8 42.1 45.1 41.1 33.0 32.4 40.6 45.8 45.5 44.4 41.9
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.6 22.8 20.8 20.3 26.1 25.5 22.0 18.4 22.5 24.4 23.3 23.0 22.6
Milner ROR 6.3 6.2 0.0 0.0 14.2 14.2 5.9 6.7 0.0 0.0 1.7 5.0 5.0
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 12.0 6.5 8.8 11.0 12.0 10.1
Swan Falls ROR 15.1 15.0 14.9 14.4 15.4 14.3 11.9 11.4 13.7 15.4 15.4 15.2 14.3
Twin Falls ROR 9.4 9.0 3.8 0.0 17.0 17.8 10.0 11.0 0.0 5.2 7.1 8.8 8.3
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.6 13.9 12.5 12.2 16.7 16.0 13.2 10.7 13.6 14.9 14.0 13.9 13.8
Upper Salmon 3&4 ROR 12.9 13.1 11.9 11.6 15.5 14.9 12.5 10.3 12.8 14.0 13.2 13.1 13.0
HCC Total 449.4 447.6 552.0 568.2 654.6 479.0 482.3 352.9 360.0 367.4 366.5 435.0 459.6
ROR Total 198.4 197.8 176.0 192.5 301.3 310.8 270.5 236.2 205.4 204.1 191.3 197.8 223.5
Total 647.8 645.4 728.0 760.7 955.9 789.8 752.8 589.1 565.4 571.5 557.8 632.8 683.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource Type 1/2014 2/2014 3/2014 4/2014 5/2014 6/2014 7/2014 8/2014 9/2014 10/2014 11/2014 12/2014 aMW
Brownlee HCC* 200.2 198.4 243.1 251.0 293.7 212.4 213.6 149.6 151.7 155.3 158.9 193.6 201.8
Oxbow HCC 83.3 82.4 101.1 104.5 118.9 88.0 90.2 68.0 69.8 70.4 69.7 80.6 85.6
Hells Canyon HCC 164.8 163.9 204.6 212.0 241.4 177.2 177.2 133.6 136.9 138.9 138.1 159.4 170.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 0.0 29.9 71.0 86.0 83.8 56.4 25.6 9.0 0.0 0.0 30.1
Bliss ROR 35.2 35.2 33.7 32.5 38.3 37.1 33.6 30.3 35.2 37.6 35.9 35.7 35.0
C .J. Strike ROR 44.6 44.1 43.4 41.9 45.1 40.7 32.8 32.2 40.5 45.6 45.3 44.3 41.7
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.5 22.5 20.7 20.1 25.7 25.4 21.8 18.2 22.3 24.3 23.1 22.9 22.5
Milner ROR 6.3 6.2 0.0 0.0 12.6 12.6 5.9 6.7 0.0 0.0 1.7 4.9 4.7
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 12.0 6.5 8.8 10.7 12.0 10.1
Swan Falls ROR 15.0 15.0 14.8 14.3 15.3 14.1 11.9 11.2 13.7 15.3 15.3 15.1 14.3
Twin Falls ROR 9.4 9.0 3.8 0.0 16.2 16.6 10.0 11.0 0.0 5.2 6.8 8.7 8.1
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.6 13.7 12.4 12 16.3 15.9 13.1 10.5 13.4 14.8 13.9 13.8 13.6
Upper Salmon 3&4 ROR 12.8 12.9 11.8 11.5 15.2 14.8 12.4 10.2 12.7 13.8 13.1 13 12.9
HCC Total 448.3 444.7 548.8 567.5 654.0 477.6 481.0 351.2 358.4 364.6 366.7 433.6 458.0
ROR Total 197.9 196.8 175.0 191.7 297.1 306.2 269.8 235.2 204.6 203.1 189.8 197.0 222.0
Total 646.2 641.5 723.8 759.2 951.1 783.8 750.8 586.4 563.0 567.7 556.5 630.6 680.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 122 2013 Integrated Resource Plan—Appendix C
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* 200.9 198.7 245.8 251.4 294.2 212.6 213.6 149.4 151.5 156.3 158.5 193.9 202.2
Oxbow HCC 83.5 82.5 102.2 104.6 119.1 88.1 90.2 68.0 69.7 70.9 69.6 80.8 85.8
Hells Canyon HCC 165.3 164.2 206.8 212.4 241.8 177.4 177.2 133.5 136.7 139.8 137.9 159.7 171.1
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.9 30.7 71.2 87.6 84.4 58.9 25.9 10.1 0.0 0.0 31.3
Bliss ROR 35.2 35.4 33.9 32.8 39.6 38.3 33.5 30.2 35.2 37.7 35.9 35.6 35.3
C .J. Strike ROR 44.5 44.1 43.9 41.9 46.6 42.3 32.8 32.1 40.5 46.0 45.2 44.6 42.0
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.5 22.7 20.8 20.3 26.8 25.8 21.8 18.1 22.3 24.5 23.3 22.9 22.7
Milner ROR 6.3 6.3 0.0 0.0 15.5 15.5 5.9 6.7 0.0 0.0 2.4 5.0 5.3
Shoshone Falls ROR 12.0 12.0 7.3 4.0 12.0 12.0 12.0 12.0 6.5 9.7 11.4 12.0 10.2
Swan Falls ROR 15.1 14.9 14.9 14.3 15.8 14.5 11.9 11.2 13.7 15.4 15.3 15.2 14.4
Twin Falls ROR 9.4 9.2 3.8 0.0 18.3 19.1 10.0 11.0 0.0 6.0 7.5 8.9 8.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.6 13.9 12.5 12.2 17.1 16.2 13.1 10.5 13.5 15.0 14.1 13.8 13.8
Upper Salmon 3&4 ROR 12.8 13.1 11.9 11.6 15.9 15.1 12.4 10.2 12.7 14.0 13.2 13.0 13.0
HCC Total 449.7 445.4 554.8 568.4 655.1 478.1 481.0 350.9 357.9 367.0 366.0 434.4 459.1
ROR Total 197.9 197.8 183.0 193.4 308.3 317.4 270.3 237.4 205.0 207.1 192.3 197.6 225.6
Total 647.6 643.2 737.8 761.8 963.4 795.5 751.3 588.3 562.9 574.1 558.3 632.0 684.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 200.5 199.1 245.2 251.1 293.9 212.1 213.1 136.5 150.8 155.4 158.7 193.4 200.8
Oxbow HCC 83.4 82.7 102.0 104.5 118.9 87.9 89.9 61.9 69.4 70.4 69.7 80.5 85.1
Hells Canyon HCC 165.0 164.5 206.3 212.1 241.6 177.0 176.7 122.0 136.0 139.0 138.0 159.3 169.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.9 30.5 71.3 87.6 84.3 55.9 27.5 10.2 0.0 0.0 31.2
Bliss ROR 35.1 35.4 33.8 32.7 39.6 38.3 33.5 26.5 35.2 37.6 35.8 35.5 34.9
C .J. Strike ROR 44.4 44.0 43.9 41.4 46.5 42.2 32.7 27.3 40.4 45.8 45.1 44.5 41.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.4 22.8 20.7 20.3 26.8 25.7 21.7 14.9 22.3 24.4 23.2 22.8 22.3
Milner ROR 6.3 7.3 0.0 0.0 15.5 15.5 5.9 0.0 0.0 0.0 2.5 5.1 4.8
Shoshone Falls ROR 12.0 12.0 7.3 4.0 12.0 12.0 12.0 6.6 6.5 9.8 11.5 12.0 9.8
Swan Falls ROR 15.0 14.9 15.0 14.1 15.8 14.5 11.8 9.7 13.6 15.4 15.3 15.2 14.2
Twin Falls ROR 9.4 9.7 3.8 0.0 18.3 19.2 10.0 0.0 0.0 6.1 7.5 9.0 7.8
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.5 13.9 12.4 12.2 17.2 16.1 13.0 8.0 13.4 14.9 14.0 13.7 13.5
Upper Salmon 3&4 ROR 12.7 13.1 11.8 11.6 15.9 15.0 12.3 8.1 12.7 13.9 13.1 13.0 12.8
HCC Total 448.9 446.3 553.5 567.7 654.4 477.0 479.7 320.4 356.2 364.8 366.4 433.2 455.7
ROR Total 197.3 199.3 182.7 192.4 308.4 317.1 269.7 193.5 206.3 206.8 192.0 197.4 221.9
Total 646.2 645.6 736.2 760.1 962.8 794.1 749.4 513.9 562.5 571.6 558.4 630.6 677.6
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 123
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* 200.1 198.8 244.6 250.8 293.6 211.6 212.6 136.0 150.2 154.4 159.0 192.9 200.4
Oxbow HCC 83.2 82.6 101.7 104.4 118.8 87.7 89.7 61.7 69.1 69.9 69.8 80.4 84.9
Hells Canyon HCC 164.7 164.2 205.8 211.9 241.4 176.6 176.3 121.5 135.5 138.0 138.2 158.9 169.4
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.0 30.5 71.1 87.1 84.3 55.9 27.7 10.1 0.0 0.0 31.1
Bliss ROR 35.0 35.2 33.8 32.7 39.3 38.0 33.3 26.3 35.1 37.5 35.7 35.4 34.8
C .J. Strike ROR 44.3 43.9 43.7 41.1 46.4 42.1 32.5 27.1 40.3 45.8 44.9 44.4 41.4
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.3 22.7 20.7 20.2 26.5 25.6 21.6 14.8 22.1 24.3 23.0 22.7 22.2
Milner ROR 6.3 6.3 0.0 0.0 15.0 15.0 5.9 0.0 0.0 0.0 2.5 5.2 4.7
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 9.8 11.5 12.0 9.8
Swan Falls ROR 15.0 14.9 14.9 14.2 15.7 14.4 11.8 9.6 13.5 15.4 15.2 15.1 14.1
Twin Falls ROR 9.5 9.2 3.8 0.0 17.9 18.3 10.0 0.0 0.0 6.1 7.5 9.0 7.6
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.4 13.9 12.4 12.1 17.0 16.0 12.9 7.9 13.3 14.8 13.9 13.7 13.4
Upper Salmon 3&4 ROR 12.7 13.1 11.8 11.6 15.7 14.9 12.3 8.0 12.6 13.9 13.1 12.9 12.7
HCC Total 448.0 445.6 552.1 567.1 653.8 475.9 478.6 319.2 354.8 362.3 367.0 432.2 454.7
ROR Total 197.0 197.4 182.5 191.9 306.1 314.4 269.1 192.7 205.8 206.4 191.3 197.0 221.0
Total 645.0 643.0 734.6 759.0 959.9 790.3 747.7 511.9 560.6 568.7 558.3 629.2 675.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 199.5 197.4 242.0 250.4 293.4 211.1 212.0 135.3 149.5 153.6 158.9 192.5 199.6
Oxbow HCC 83.0 82.0 100.6 104.2 118.7 87.5 89.5 61.3 68.8 69.6 69.7 80.2 84.6
Hells Canyon HCC 164.2 163.1 203.7 211.6 241.2 176.2 175.9 120.9 134.9 137.3 138.0 158.6 168.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.9 31.4 70.9 86.2 84.3 55.8 27.6 10.1 0.0 0.0 31.1
Bliss ROR 34.9 35.2 33.7 32.6 38.8 37.3 33.1 26.1 34.8 37.3 35.4 35.2 34.5
C .J. Strike ROR 44.1 43.7 43.6 41.1 45.8 41.3 32.3 26.9 40.2 45.7 44.6 44.3 41.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.2 22.5 20.6 20.1 26.3 25.4 21.4 14.6 21.9 24.2 22.9 22.5 22.1
Milner ROR 6.3 6.3 0.0 0.0 13.9 13.9 5.9 0.0 0.0 0.0 2.6 5.0 4.5
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 9.5 11.6 12.0 9.8
Swan Falls ROR 15.0 14.8 14.8 14.1 15.4 14.1 11.7 9.5 13.4 15.3 15.1 15.1 14.0
Twin Falls ROR 9.5 9.2 3.8 0.0 16.8 17.4 10.0 0.0 0.0 5.7 7.6 8.9 7.4
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.4 13.7 12.3 12.0 16.8 15.9 12.8 7.8 13.1 14.7 13.7 13.6 13.3
Upper Salmon 3&4 ROR 12.6 12.9 11.8 11.5 15.6 14.8 12.2 7.9 12.4 13.8 12.9 12.8 12.6
HCC Total 446.7 442.5 546.3 566.2 653.3 474.8 477.4 317.5 353.2 360.5 366.6 431.3 453.0
ROR Total 196.5 196.5 181.9 192.3 301.8 309.3 268.2 191.7 204.6 205.0 190.4 196.0 219.5
Total 643.2 639.0 728.2 758.5 955.1 784.1 745.6 509.2 557.8 565.5 557.0 627.3 672.5
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 124 2013 Integrated Resource Plan—Appendix C
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* 199.1 197.1 240.6 250.1 293.0 210.6 211.5 134.7 148.9 152.2 159.2 192.0 199.1
Oxbow HCC 82.8 81.8 100.0 104.1 118.6 87.3 89.3 61.1 68.5 68.9 69.8 79.9 84.3
Hells Canyon HCC 163.9 162.8 202.6 211.4 240.9 175.8 175.4 120.4 134.4 136.0 138.2 158.1 168.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 7.2 30.2 70.5 85.9 84.2 55.8 27.4 10.3 0.0 0.0 31.0
Bliss ROR 34.8 35.1 33.6 32.5 38.6 37.1 32.9 25.9 34.7 37.2 35.3 35.1 34.4
C .J. Strike ROR 43.9 43.6 43.5 40.9 44.9 40.8 32.1 26.7 40.0 45.5 44.4 43.8 40.8
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.1 22.4 20.6 20.0 26.1 25.3 21.3 14.5 21.7 24.1 22.6 22.4 21.9
Milner ROR 6.3 6.3 0.0 0.0 12.7 12.7 5.9 0.0 0.0 0.0 2.0 5.0 4.2
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 9.5 11.3 12.0 9.8
Swan Falls ROR 15.0 14.8 14.8 14.1 15.4 13.9 11.6 9.5 13.4 15.3 15.0 14.9 14.0
Twin Falls ROR 9.5 9.2 3.8 0.0 15.9 16.5 10.0 0.0 0.0 5.7 7.4 8.9 7.2
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.3 13.6 12.3 12.0 16.7 15.8 12.7 7.7 13.0 14.6 13.5 13.4 13.2
Upper Salmon 3&4 ROR 12.6 12.9 11.7 11.4 15.5 14.7 12.1 7.8 12.3 13.7 12.8 12.7 12.5
HCC Total 445.8 441.7 543.2 565.6 652.5 473.7 476.2 316.2 351.8 357.1 367.2 430.0 451.8
ROR Total 196.0 196.1 181.9 190.6 297.8 305.7 267.3 191.0 203.7 204.6 188.3 194.8 218.1
Total 641.8 637.8 725.1 756.2 950.3 779.4 743.5 507.2 555.5 561.7 555.5 624.8 669.9
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 198.0 196.6 240.2 249.8 292.7 210.0 210.9 134.1 148.3 150.7 159.1 191.9 198.5
Oxbow HCC 82.4 81.6 99.9 104.0 118.5 87.0 89.0 60.8 68.2 68.1 69.7 79.9 84.1
Hells Canyon HCC 163.0 162.4 202.3 211.1 240.6 175.3 174.9 119.8 133.8 134.6 138.0 158.0 167.8
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.9 30.2 70.3 85.8 84.2 55.8 27.1 10.3 0.0 0.0 30.9
Bliss ROR 34.7 34.8 33.5 32.4 38.4 36.8 32.8 25.8 34.5 37.2 35.1 34.9 34.2
C .J. Strike ROR 43.8 43.4 43.4 40.8 44.7 40.4 31.9 26.4 39.9 45.4 44.2 43.6 40.7
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 22.0 22.2 20.5 20.0 25.8 25.1 21.1 14.3 21.5 23.9 22.4 22.2 21.8
Milner ROR 6.3 5.8 0.0 0.0 12.3 12.3 5.9 0.0 0.0 0.0 1.8 5.0 4.1
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 9.5 11.3 12.0 9.8
Swan Falls ROR 14.8 14.7 14.8 14.0 15.3 13.8 11.6 9.4 13.3 15.2 15.0 14.9 13.9
Twin Falls ROR 9.5 8.9 3.8 0.0 15.1 15.8 10.0 0.0 0.0 5.7 7.4 8.8 7.1
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.2 13.5 12.3 11.9 16.4 15.7 12.6 7.5 12.8 14.5 13.4 13.3 13.1
Upper Salmon 3&4 ROR 12.5 12.8 11.7 11.4 15.2 14.6 12.0 7.7 12.2 13.6 12.6 12.6 12.4
HCC Total 443.4 440.6 542.4 564.9 651.8 472.3 474.8 314.7 350.3 353.4 366.8 429.8 450.4
ROR Total 195.3 194.3 181.3 190.2 295.0 303.3 266.6 190.0 202.5 204.0 187.2 193.9 217.0
Total 638.7 634.9 723.7 755.1 946.8 775.6 741.4 504.7 552.8 557.4 554.0 623.7 667.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 125
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* 197.5 196.1 239.9 249.4 292.3 209.3 210.2 133.5 147.5 148.5 159.3 191.2 197.9
Oxbow HCC 82.2 81.4 99.7 103.8 118.3 86.7 88.7 60.5 67.8 67.0 69.7 79.6 83.8
Hells Canyon HCC 162.6 162.1 202.0 210.7 240.4 174.7 174.4 119.3 133.1 132.5 138.1 157.4 167.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.8 30.8 70.3 85.6 84.1 55.3 26.9 9.9 0.0 0.0 30.8
Bliss ROR 34.5 34.8 33.4 32.4 38.1 36.6 32.6 25.6 34.2 37.1 34.8 34.8 34.1
C .J. Strike ROR 43.6 43.3 43.3 40.8 44.5 40.0 31.7 26.2 39.7 45.1 43.8 43.4 40.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.9 22.1 20.4 19.9 25.6 25.0 21.0 14.1 21.3 23.7 22.2 22.1 21.6
Milner ROR 6.3 6.2 0.0 0.0 12.3 12.3 5.9 0.0 0.0 0.0 1.8 4.9 4.1
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 9.4 11.1 12.0 9.7
Swan Falls ROR 14.8 14.7 14.7 14.1 15.2 13.7 11.5 9.3 13.3 15.2 14.9 14.8 13.9
Twin Falls ROR 9.5 9.0 3.8 0.0 15.5 16.6 10.0 0.0 0.0 5.7 7.2 8.8 7.2
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.1 13.4 12.2 11.8 16.3 15.6 12.5 7.4 12.7 14.3 13.2 13.2 13.0
Upper Salmon 3&4 ROR 12.4 12.7 11.6 11.3 15.1 14.5 11.9 7.6 12.0 13.5 12.5 12.5 12.3
HCC Total 442.3 439.6 541.6 563.9 651.0 470.7 473.3 313.3 348.4 348.0 367.1 428.2 449.0
ROR Total 194.6 194.4 180.6 190.6 294.3 302.9 265.7 188.6 201.3 202.6 185.5 193.1 216.2
Total 636.9 634.0 722.2 754.5 945.3 773.6 739.0 501.9 549.7 550.6 552.6 621.3 665.1
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 196.9 195.6 238.9 248.9 292.0 208.7 209.5 132.7 146.8 146.8 159.5 190.5 197.2
Oxbow HCC 81.9 81.2 99.3 103.6 118.2 86.5 88.4 60.1 67.5 66.2 69.8 79.3 83.5
Hells Canyon HCC 162.1 161.7 201.2 210.4 240.1 174.2 173.8 118.6 132.5 131.0 138.2 156.9 166.7
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.6 30.6 70.0 85.5 84.2 55.3 26.9 9.9 0.0 0.0 30.7
Bliss ROR 34.4 34.6 33.3 32.1 38.1 36.2 32.3 25.4 34.0 37.0 34.7 34.7 33.9
C .J. Strike ROR 43.4 43.1 43.0 40.7 44.4 39.5 31.4 25.9 39.5 44.9 43.5 43.2 40.2
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.8 22.0 20.3 19.5 25.4 24.7 20.8 14.0 21.1 23.5 22.0 22.0 21.4
Milner ROR 6.3 5.8 0.0 0.0 12.2 12.2 5.9 0.0 0.0 0.0 1.7 4.9 4.1
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.9 12.0 9.7
Swan Falls ROR 14.7 14.7 14.7 14.0 15.2 13.6 11.4 9.2 13.2 15.1 14.8 14.8 13.8
Twin Falls ROR 9.5 8.9 3.8 0.0 15.0 16.0 10.0 0.0 0.0 5.2 7.0 8.8 7.0
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 13.0 13.3 12.1 11.5 16.1 15.4 12.3 7.3 12.5 14.2 13.1 13.1 12.8
Upper Salmon 3&4 ROR 12.3 12.6 11.6 11.1 15.0 14.3 11.7 7.5 11.9 13.4 12.4 12.4 12.2
HCC Total 440.9 438.5 539.4 562.9 650.3 469.4 471.7 311.4 346.8 344.0 367.5 426.7 447.5
ROR Total 193.9 193.2 179.8 189.0 292.9 300.4 264.5 187.7 200.3 200.7 184.1 192.5 214.9
Total 634.8 631.7 719.2 751.9 943.2 769.8 736.2 499.1 547.1 544.7 551.6 619.2 662.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 126 2013 Integrated Resource Plan—Appendix C
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* 196.1 195.2 239.1 248.6 291.6 208.1 208.9 131.9 146.2 146.3 159.4 190.1 196.8
Oxbow HCC 81.5 81.1 99.4 103.5 118.0 86.2 88.2 59.8 67.2 66.0 69.7 79.1 83.3
Hells Canyon HCC 161.4 161.3 201.4 210.1 239.8 173.8 173.3 117.9 131.9 130.5 138.1 156.5 166.3
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.6 30.5 69.8 85.2 84.3 55.1 26.9 10.1 0.0 0.0 30.7
Bliss ROR 34.3 34.5 33.2 32.0 38.0 35.9 32.1 25.2 33.8 36.9 34.5 34.5 33.7
C .J. Strike ROR 43.1 43.0 43.0 40.7 44.2 38.8 31.2 25.7 39.2 44.6 43.3 43.0 40.0
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.7 21.9 20.2 19.4 25.2 24.4 20.6 13.8 20.9 23.3 21.9 21.9 21.3
Milner ROR 6.2 5.8 0.0 0.0 11.3 11.3 5.9 0.0 0.0 0.0 1.7 4.9 3.9
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 11.1 12.0 9.7
Swan Falls ROR 14.7 14.7 14.6 13.9 15.0 13.3 11.4 9.1 13.2 15.0 14.7 14.7 13.7
Twin Falls ROR 9.4 8.9 3.8 0.0 14.0 15.1 10.0 0.0 0.0 5.2 7.2 8.8 6.9
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.9 13.3 12.1 11.5 15.9 15.1 12.2 7.2 12.3 14.1 13.0 13.0 12.7
Upper Salmon 3&4 ROR 12.3 12.6 11.5 11.0 14.8 14.1 11.6 7.4 11.8 13.2 12.3 12.3 12.1
HCC Total 439.0 437.6 539.9 562.2 649.4 468.1 470.4 309.6 345.3 342.8 367.2 425.7 446.4
ROR Total 193.1 192.9 179.4 188.5 289.6 296.2 263.8 186.6 199.3 199.9 183.7 191.7 213.7
Total 632.1 630.5 719.3 750.7 939.0 764.3 734.2 496.2 544.6 542.7 550.9 617.4 660.2
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 195.5 194.7 238.8 248.2 283.1 207.5 208.3 131.2 145.5 144.8 159.3 189.9 195.6
Oxbow HCC 81.3 80.8 99.3 103.3 117.9 86.0 87.9 59.4 66.9 65.2 69.6 79.0 83.1
Hells Canyon HCC 160.9 160.9 201.1 209.8 241.3 173.3 172.8 117.2 131.3 129.1 137.9 156.4 166.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0 0 6.6 30.2 69.35 85.1 84.3 54.5 26.8 9.9 0 0 30.6
Bliss ROR 34.2 34.4 33.1 31.9 38 35.8 32 25 33.6 36.7 34.3 34.3 33.6
C .J. Strike ROR 43 42.8 42.9 40.4 44 38.5 31 25.4 39 44.4 43 42.8 39.8
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7 10.3 6.45 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.6 21.8 20.2 19.3 25.1 24.2 20.4 13.6 20.7 23.2 21.7 21.7 21.1
Milner ROR 6.0 5.8 0.0 0.0 10.9 10.9 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.9 12.0 9.7
Swan Falls ROR 14.6 14.6 14.6 13.9 14.9 13.2 11.2 9.0 13.2 15.0 14.6 14.6 13.6
Twin Falls ROR 9.4 8.9 3.8 0.0 13.7 14.7 10.0 0.0 0.0 5.2 7.0 8.8 6.8
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.9 13.2 12.0 11.4 15.9 15.0 12.0 7.0 12.2 13.9 12.8 12.9 12.6
Upper Salmon 3&4 ROR 12.2 12.5 11.5 10.9 14.8 14.0 11.5 7.3 11.6 13.1 12.2 12.2 12.0
HCC Total 437.7 436.4 539.2 561.3 642.3 466.8 469.0 307.8 343.7 339.1 366.8 425.3 444.6
ROR Total 192.4 192.2 179.1 187.5 288.1 294.4 262.8 184.9 198.3 198.9 182.2 190.8 212.6
Total 630.1 628.6 718.3 748.8 930.4 761.2 731.8 492.7 542.0 538.0 549.0 616.1 657.3
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 127
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* 195.0 194.1 238.3 247.7 282.7 206.9 207.6 130.4 144.8 143.6 159.4 189.4 195.0
Oxbow HCC 81.1 80.6 99.1 103.1 117.7 85.7 87.6 59.1 66.5 64.6 69.7 78.8 82.8
Hells Canyon HCC 160.5 160.4 200.8 209.4 241.1 172.8 172.2 116.5 130.7 127.9 138.0 155.9 165.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.6 30.0 69.2 85.0 84.4 54.4 26.8 9.8 0.0 0.0 30.5
Bliss ROR 34.0 34.2 33.0 31.8 37.8 35.7 31.7 24.8 33.4 36.5 34.1 34.2 33.4
C .J. Strike ROR 43.0 42.7 42.8 40.3 43.1 37.8 30.8 25.2 38.7 44.3 42.8 42.6 39.5
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.5 21.7 20.1 19.2 25 24.1 20.3 13.5 20.5 23.1 21.5 21.6 21.0
Milner ROR 6 5.8 0 0 10.7 10.7 5.9 0 0 0 1.7 4.9 3.8
Shoshone Falls ROR 12 12 7.3 3.9 12 12 12 6.6 6.5 8.8 10.8 12 9.7
Swan Falls ROR 14.6 14.6 14.6 13.8 14.7 13 11.2 8.9 13.1 14.9 14.5 14.6 13.5
Twin Falls ROR 9.4 8.9 3.8 0 13.5 14.5 10 0 0 5.2 6.9 8.8 6.8
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.8 13.1 12.0 11.3 15.8 14.9 11.9 6.9 12.0 13.9 12.7 12.8 12.5
Upper Salmon 3&4 ROR 12.1 12.4 11.4 10.9 14.7 13.9 11.4 7.2 11.5 13.1 12.0 12.1 11.9
HCC Total 436.6 435.1 538.2 560.2 641.5 465.4 467.4 306.0 342.0 336.1 367.1 424.1 443.3
ROR Total 191.9 191.6 178.7 186.8 285.9 292.6 262.1 184.0 197.2 198.3 181.0 190.2 211.7
Total 628.5 626.7 716.9 747.0 927.4 758.0 729.5 490.0 539.2 534.4 548.1 614.3 655.0
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 194.2 193.2 237.5 247.4 282.4 206.3 207.0 129.8 144.1 142.0 159.9 188.5 194.4
Oxbow HCC 80.7 80.2 98.7 103.0 117.6 85.5 87.3 58.8 66.2 63.9 69.8 78.4 82.5
Hells Canyon HCC 159.9 159.7 200.1 209.2 240.8 172.3 171.7 116.0 130.0 126.5 138.3 155.2 165.0
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.6 29.9 68.8 84.6 84.4 54.4 26.7 9.6 0.0 0.0 30.4
Bliss ROR 33.7 34.2 32.9 31.7 37.3 35.4 31.5 24.6 33.2 36.4 33.9 34.1 33.2
C .J. Strike ROR 42.9 42.5 42.7 40.2 42.1 37.6 30.6 24.9 38.5 44.1 42.5 42.4 39.3
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.3 21.5 20.0 19.1 24.4 23.7 20.2 13.3 20.3 23.0 21.4 21.4 20.8
Milner ROR 6.0 5.8 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.8 14.6 12.9 11.1 8.9 13.1 14.8 14.4 14.5 13.5
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.7 12.9 11.9 11.3 15.3 14.6 11.8 6.8 11.9 13.8 12.6 12.7 12.4
Upper Salmon 3&4 ROR 12 12.3 11.4 10.8 14.3 13.7 11.3 7.1 11.4 13 12 12.1 11.8
HCC Total 434.8 433.1 536.3 559.6 640.8 464.1 466.0 304.6 340.3 332.4 368.0 422.1 441.8
ROR Total 191.0 190.7 178.2 186.3 282.4 290.7 261.3 183.1 196.3 197.4 180.0 189.5 210.6
Total 625.8 623.8 714.5 745.9 923.2 754.8 727.3 487.7 536.6 529.8 548.0 611.6 652.4
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 128 2013 Integrated Resource Plan—Appendix C
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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Existing Resource Data
2013 Integrated Resource Plan—Appendix C Page 129
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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Existing Resource Data Idaho Power Company
Page 130 2013 Integrated Resource Plan—Appendix C
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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Average Megawatt (aMW) 90th Percentile Water, 70th 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* 193.8 192.8 236.6 247.0 282.1 205.7 206.3 129.1 143.4 140.9 160.0 180.8 193.2
Oxbow HCC 80.6 80.1 98.4 102.8 117.4 85.3 87.1 58.5 65.9 63.3 69.9 78.2 82.3
Hells Canyon HCC 159.5 159.4 199.4 208.9 240.5 171.9 171.2 115.4 129.4 125.4 138.3 154.4 164.5
1000 Springs ROR** 6.0 5.8 5.7 5.3 5.6 6.0 5.8 6.0 6.4 6.4 5.4 6.1 5.9
American Falls ROR 0.0 0.0 6.5 29.8 68.8 84.4 84.1 54.3 26.7 9.7 0.0 0.0 30.4
Bliss ROR 33.6 34.0 32.8 31.6 36.9 35.2 31.4 24.4 33.0 36.2 33.7 33.9 33.1
C .J. Strike ROR 42.8 42.4 42.5 40.0 41.9 37.4 30.4 24.6 38.2 43.9 42.3 42.2 39.1
Cascade ROR 1.4 1.4 1.3 1.3 1.5 4.2 7.0 10.3 6.5 1.4 1.3 1.3 3.2
Clear Lake ROR 1.7 1.6 1.6 1.4 1.6 1.4 1.4 1.5 1.6 1.7 1.5 1.7 1.6
Lower Malad ROR 11.1 11.2 11.9 11.3 13.0 12.0 11.7 12.0 13.0 12.8 10.1 11.2 11.8
Lowe Salmon ROR 21.2 21.4 19.9 19.1 24.3 23.5 20.0 13.2 20.2 22.8 21.2 21.3 20.7
Milner ROR 6.0 5.5 0.0 0.0 10.7 10.7 5.9 0.0 0.0 0.0 1.7 4.9 3.8
Shoshone Falls ROR 12.0 12.0 7.3 3.9 12.0 12.0 12.0 6.6 6.5 8.8 10.7 12.0 9.7
Swan Falls ROR 14.5 14.5 14.5 13.7 14.5 12.9 11.0 8.8 13.1 14.8 14.4 14.5 13.4
Twin Falls ROR 9.4 8.8 3.8 0.0 13.5 14.5 10.0 0.0 0.0 5.2 6.8 8.8 6.7
Upper Malad ROR 6.3 6.2 6.6 6.3 7.7 7.3 6.7 6.7 7.2 6.5 5.6 6.3 6.6
Upper Salmon 1&2 ROR 12.6 12.9 11.8 11.2 15.3 14.4 11.7 6.7 11.8 13.7 12.4 12.6 12.3
Upper Salmon 3&4 ROR 11.9 12.2 11.3 10.8 14.2 13.5 11.2 7.0 11.3 12.9 11.8 12.0 11.7
HCC Total 433.9 432.3 534.4 558.7 640.0 462.9 464.6 303.0 338.7 329.6 368.2 413.4 440.0
ROR Total 190.5 189.9 177.5 185.7 281.5 289.5 260.2 182.1 195.5 196.7 179.0 188.8 209.7
Total 624.4 622.2 711.9 744.4 921.5 752.4 724.8 485.1 534.2 526.3 547.2 602.2 649.7
*HCC=Hells Canyon Complex,**ROR= Run of River

Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2013 Integrated Resource Plan—Appendix C Page 131
PORTFOLIO ANALYSIS, RESULTS,
AND SUPPORTING DOCUMENTATION
Stochastic Dispersion Plot

Regulatory Environmental Compliance Costs
Portfolio Analysis Cost of CO2 Emissions

Note: Instead of assuming NOx, Hg, and SO2 emissions adders, the 2013 IRP used the Idaho Power coal study to calculate the variable and fixed environmental compliance costs attributed to these emission types.
0
1
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3
4
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Total Portfolio Cost [2013 through 2032] (NPV dollars, 000s )
Stochastics: 102 Iterations
High Carbon
Planning Carbon
Low Carbon
$-
$500,000
$1,000,000
$1,500,000
$2,000,000
$2,500,000
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Planning Carbon High Carbon
Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 132 2013 Integrated Resource Plan—Appendix C
Loss of Load Expectation Analysis
Loss of Load Expectation Summary Data*–Portfolio 1
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2019 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2020 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00
2021 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2022 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2023 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00
2024 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.00 0.00 0.00 0.00 0.00
2025 0.20 0.00 0.00 0.00 0.00 0.00 0.00 0.19 0.00 0.00 0.00 0.00 0.00
2026 0.20 0.00 0.00 0.00 0.00 0.00 0.00 0.19 0.00 0.00 0.00 0.00 0.01
2027 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.13 0.00 0.00 0.00 0.00 0.01
2028 0.29 0.00 0.00 0.00 0.00 0.00 0.01 0.26 0.00 0.00 0.00 0.00 0.02
2029 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00
2030 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00
2031 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00
2032 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00
* With CBM@330 MW

Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2013 Integrated Resource Plan—Appendix C Page 133
Loss of Load Expectation Summary Data*–Portfolio 2
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2019 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2020 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00
2021 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2022 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2023 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00
2024 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00
2025 0.17 0.00 0.00 0.00 0.00 0.00 0.00 0.16 0.00 0.00 0.00 0.00 0.00
2026 0.17 0.00 0.00 0.00 0.00 0.00 0.00 0.16 0.00 0.00 0.00 0.00 0.01
2027 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.01
2028 0.21 0.00 0.00 0.00 0.00 0.00 0.01 0.18 0.00 0.00 0.00 0.00 0.02
2029 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
2030 0.25 0.00 0.00 0.00 0.00 0.00 0.00 0.24 0.00 0.00 0.00 0.00 0.00
2031 0.91 0.00 0.00 0.00 0.00 0.00 0.00 0.90 0.00 0.00 0.00 0.00 0.00
2032 0.36 0.00 0.00 0.00 0.00 0.00 0.00 0.34 0.00 0.00 0.00 0.00 0.01
* With CBM@330 MW

Loss of Load Expectation Summary Data*–Portfolio 3
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.74 0.00 0.00 0.00 0.00 0.00 0.03 0.69 0.01 0.01 0.00 0.00 0.00
2014 1.24 0.00 0.00 0.00 0.00 0.00 0.01 1.21 0.01 0.00 0.00 0.00 0.01
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.97 0.00 0.00 0.00 0.00 0.01 0.44 0.30 0.18 0.02 0.00 0.00 0.01
2019 1.42 0.00 0.00 0.00 0.00 0.04 0.36 0.57 0.37 0.08 0.00 0.00 0.01
2020 3.30 0.00 0.00 0.00 0.00 0.10 0.26 1.19 1.68 0.04 0.00 0.00 0.02
2021 2.61 0.01 0.00 0.00 0.00 0.05 0.25 1.59 0.52 0.11 0.00 0.00 0.07
2022 0.28 0.00 0.00 0.00 0.00 0.01 0.06 0.14 0.05 0.01 0.00 0.00 0.01
2023 0.46 0.00 0.00 0.00 0.00 0.01 0.09 0.28 0.06 0.01 0.00 0.00 0.01
2024 0.94 0.00 0.00 0.00 0.00 0.01 0.07 0.69 0.08 0.09 0.00 0.00 0.01
2025 2.01 0.00 0.00 0.00 0.00 0.00 0.03 1.86 0.06 0.05 0.00 0.00 0.01
2026 2.01 0.00 0.00 0.00 0.00 0.01 0.04 1.83 0.10 0.02 0.00 0.00 0.01
2027 1.35 0.00 0.00 0.00 0.00 0.00 0.05 1.22 0.05 0.01 0.00 0.00 0.02
2028 2.30 0.00 0.00 0.00 0.00 0.01 0.14 2.06 0.05 0.02 0.00 0.00 0.02
2029 1.05 0.00 0.00 0.00 0.00 0.00 0.05 0.98 0.01 0.01 0.00 0.00 0.01
2030 2.55 0.00 0.00 0.00 0.00 0.00 0.06 2.45 0.02 0.01 0.00 0.00 0.01
2031 6.75 0.00 0.00 0.00 0.00 0.00 0.05 6.67 0.03 0.00 0.00 0.00 0.01
2032 3.28 0.00 0.00 0.00 0.00 0.00 0.08 3.15 0.02 0.00 0.00 0.00 0.02
* With CBM@330 MW
Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 134 2013 Integrated Resource Plan—Appendix C
Loss of Load Expectation Summary Data*–Portfolio 4
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.14 0.00 0.00 0.00 0.00 0.00 0.05 0.07 0.02 0.00 0.00 0.00 0.00
2019 0.20 0.00 0.00 0.00 0.00 0.00 0.04 0.12 0.04 0.01 0.00 0.00 0.00
2020 0.47 0.00 0.00 0.00 0.00 0.01 0.03 0.24 0.19 0.00 0.00 0.00 0.00
2021 0.29 0.00 0.00 0.00 0.00 0.00 0.03 0.19 0.05 0.01 0.00 0.00 0.01
2022 0.29 0.00 0.00 0.00 0.00 0.01 0.06 0.16 0.05 0.01 0.00 0.00 0.01
2023 0.49 0.00 0.00 0.00 0.00 0.01 0.09 0.32 0.06 0.01 0.00 0.00 0.01
2024 1.01 0.00 0.00 0.00 0.00 0.01 0.07 0.76 0.08 0.09 0.00 0.00 0.01
2025 2.18 0.00 0.00 0.00 0.00 0.00 0.03 2.03 0.06 0.05 0.00 0.00 0.01
2026 0.27 0.00 0.00 0.00 0.00 0.00 0.00 0.25 0.01 0.00 0.00 0.00 0.00
2027 0.18 0.00 0.00 0.00 0.00 0.00 0.01 0.17 0.00 0.00 0.00 0.00 0.00
2028 0.32 0.00 0.00 0.00 0.00 0.00 0.01 0.30 0.01 0.00 0.00 0.00 0.00
2029 0.55 0.00 0.00 0.00 0.00 0.00 0.02 0.51 0.01 0.00 0.00 0.00 0.00
2030 1.33 0.00 0.00 0.00 0.00 0.00 0.03 1.28 0.01 0.00 0.00 0.00 0.00
2031 3.63 0.00 0.00 0.00 0.00 0.00 0.02 3.59 0.01 0.00 0.00 0.00 0.00
2032 1.75 0.00 0.00 0.00 0.00 0.00 0.04 1.69 0.01 0.00 0.00 0.00 0.01
* With CBM@330 MW

Loss of Load Expectation Summary Data*–Portfolio 5
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.14 0.00 0.00 0.00 0.00 0.00 0.05 0.07 0.02 0.00 0.00 0.00 0.00
2019 0.20 0.00 0.00 0.00 0.00 0.00 0.04 0.12 0.04 0.01 0.00 0.00 0.00
2020 0.47 0.00 0.00 0.00 0.00 0.01 0.03 0.24 0.19 0.00 0.00 0.00 0.00
2021 0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.01 0.00 0.00 0.00 0.00
2022 0.05 0.00 0.00 0.00 0.00 0.00 0.01 0.04 0.01 0.00 0.00 0.00 0.00
2023 0.09 0.00 0.00 0.00 0.00 0.00 0.01 0.08 0.01 0.00 0.00 0.00 0.00
2024 0.20 0.00 0.00 0.00 0.00 0.00 0.01 0.18 0.01 0.01 0.00 0.00 0.00
2025 0.49 0.00 0.00 0.00 0.00 0.00 0.00 0.47 0.01 0.00 0.00 0.00 0.00
2026 0.27 0.00 0.00 0.00 0.00 0.00 0.00 0.25 0.01 0.00 0.00 0.00 0.00
2027 0.18 0.00 0.00 0.00 0.00 0.00 0.01 0.17 0.00 0.00 0.00 0.00 0.00
2028 0.32 0.00 0.00 0.00 0.00 0.00 0.01 0.30 0.01 0.00 0.00 0.00 0.00
2029 0.55 0.00 0.00 0.00 0.00 0.00 0.02 0.51 0.01 0.00 0.00 0.00 0.00
2030 1.33 0.00 0.00 0.00 0.00 0.00 0.03 1.28 0.01 0.00 0.00 0.00 0.00
2031 3.63 0.00 0.00 0.00 0.00 0.00 0.02 3.59 0.01 0.00 0.00 0.00 0.00
2032 1.75 0.00 0.00 0.00 0.00 0.00 0.04 1.69 0.01 0.00 0.00 0.00 0.01
* With CBM@330 MW
Idaho Power Company Portfolio Analysis, Results, and Supporting Documentation
2013 Integrated Resource Plan—Appendix C Page 135
Loss of Load Expectation Summary Data*–Portfolio 6
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.45 0.00 0.00 0.00 0.00 0.00 0.01 0.41 0.00 0.00 0.00 0.00 0.01
2017 2.59 0.01 0.00 0.00 0.00 0.00 0.16 2.29 0.04 0.01 0.00 0.00 0.07
2018 0.04 0.00 0.00 0.00 0.00 0.00 0.02 0.02 0.00 0.00 0.00 0.00 0.00
2019 0.06 0.00 0.00 0.00 0.00 0.00 0.01 0.03 0.01 0.00 0.00 0.00 0.00
2020 0.15 0.00 0.00 0.00 0.00 0.00 0.01 0.07 0.06 0.00 0.00 0.00 0.01
2021 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.01 0.00 0.00 0.00 0.02
2022 0.07 0.00 0.00 0.00 0.00 0.00 0.01 0.03 0.01 0.00 0.00 0.00 0.02
2023 0.11 0.00 0.00 0.00 0.00 0.00 0.02 0.06 0.01 0.00 0.00 0.00 0.02
2024 0.22 0.01 0.00 0.00 0.00 0.00 0.01 0.15 0.01 0.02 0.00 0.00 0.02
2025 0.44 0.00 0.00 0.00 0.00 0.00 0.01 0.39 0.01 0.01 0.00 0.00 0.02
2026 0.44 0.00 0.00 0.00 0.00 0.00 0.01 0.38 0.02 0.00 0.00 0.00 0.03
2027 0.34 0.01 0.00 0.00 0.00 0.00 0.01 0.27 0.01 0.00 0.00 0.00 0.05
2028 0.55 0.01 0.00 0.00 0.00 0.00 0.02 0.44 0.01 0.00 0.00 0.00 0.06
2029 0.90 0.01 0.00 0.00 0.00 0.00 0.04 0.76 0.01 0.01 0.00 0.00 0.07
2030 2.18 0.01 0.00 0.00 0.00 0.00 0.05 2.03 0.02 0.01 0.00 0.00 0.07
2031 3.97 0.01 0.00 0.00 0.00 0.00 0.03 3.85 0.01 0.00 0.00 0.00 0.06
2032 2.03 0.01 0.00 0.00 0.00 0.00 0.05 1.85 0.01 0.00 0.00 0.00 0.11
* With CBM@330 MW

Loss of Load Expectation Summary Data*–Portfolio 7
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.78 0.00 0.00 0.00 0.00 0.00 0.01 0.75 0.01 0.00 0.00 0.00 0.01
2016 0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00
2017 0.31 0.00 0.00 0.00 0.00 0.00 0.02 0.28 0.00 0.00 0.00 0.00 0.01
2018 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2019 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2020 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00
2021 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.01 0.00 0.00 0.00 0.01
2022 0.06 0.00 0.00 0.00 0.00 0.00 0.01 0.02 0.01 0.00 0.00 0.00 0.02
2023 0.09 0.00 0.00 0.00 0.00 0.00 0.01 0.05 0.01 0.00 0.00 0.00 0.02
2024 0.18 0.01 0.00 0.00 0.00 0.00 0.01 0.12 0.01 0.01 0.00 0.00 0.02
2025 0.36 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.01 0.01 0.00 0.00 0.02
2026 0.36 0.00 0.00 0.00 0.00 0.00 0.01 0.31 0.02 0.00 0.00 0.00 0.02
2027 0.28 0.01 0.00 0.00 0.00 0.00 0.01 0.21 0.01 0.00 0.00 0.00 0.04
2028 0.44 0.01 0.00 0.00 0.00 0.00 0.02 0.36 0.01 0.00 0.00 0.00 0.05
2029 0.73 0.01 0.00 0.00 0.00 0.00 0.03 0.61 0.01 0.00 0.00 0.00 0.06
2030 1.68 0.01 0.00 0.00 0.00 0.00 0.04 1.55 0.01 0.01 0.00 0.00 0.05
2031 3.95 0.01 0.00 0.00 0.00 0.00 0.03 3.81 0.02 0.00 0.00 0.00 0.08
2032 2.20 0.02 0.00 0.00 0.00 0.00 0.05 1.97 0.02 0.00 0.00 0.00 0.14
* With CBM@330 MW
Portfolio Analysis, Results, and Supporting Documentation Idaho Power Company
Page 136 2013 Integrated Resource Plan—Appendix C
Loss of Load Expectation Summary Data*–Portfolio 8
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2019 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2020 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.00 0.00 0.00 0.00
2021 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.00 0.00 0.00 0.00 0.00
2022 0.06 0.00 0.00 0.00 0.00 0.00 0.01 0.02 0.01 0.00 0.00 0.00 0.02
2023 0.10 0.00 0.00 0.00 0.00 0.00 0.02 0.05 0.01 0.00 0.00 0.00 0.02
2024 0.19 0.00 0.00 0.00 0.00 0.00 0.01 0.14 0.01 0.01 0.00 0.00 0.02
2025 0.51 0.00 0.00 0.00 0.00 0.00 0.01 0.47 0.01 0.01 0.00 0.00 0.02
2026 1.70 0.01 0.00 0.00 0.00 0.00 0.03 1.49 0.06 0.01 0.00 0.00 0.09
2027 0.14 0.01 0.00 0.00 0.00 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.02
2028 0.21 0.00 0.00 0.00 0.00 0.00 0.01 0.18 0.00 0.00 0.00 0.00 0.02
2029 0.39 0.00 0.00 0.00 0.00 0.00 0.01 0.34 0.00 0.00 0.00 0.00 0.02
2030 0.98 0.00 0.00 0.00 0.00 0.00 0.02 0.94 0.00 0.00 0.00 0.00 0.02
2031 3.02 0.00 0.00 0.00 0.00 0.00 0.01 2.96 0.01 0.00 0.00 0.00 0.03
2032 1.34 0.00 0.00 0.00 0.00 0.00 0.02 1.24 0.01 0.00 0.00 0.00 0.06
* With CBM@330 MW

Loss of Load Expectation Summary Data*–Portfolio 9
Year Annual Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
2013 0.42 0.00 0.00 0.00 0.00 0.00 0.01 0.40 0.00 0.00 0.00 0.00 0.00
2014 0.79 0.00 0.00 0.00 0.00 0.00 0.01 0.78 0.00 0.00 0.00 0.00 0.00
2015 0.63 0.00 0.00 0.00 0.00 0.00 0.01 0.61 0.01 0.00 0.00 0.00 0.00
2016 0.35 0.00 0.00 0.00 0.00 0.00 0.01 0.32 0.00 0.00 0.00 0.00 0.01
2017 0.58 0.00 0.00 0.00 0.00 0.00 0.03 0.53 0.01 0.00 0.00 0.00 0.01
2018 0.97 0.00 0.00 0.00 0.00 0.01 0.44 0.30 0.18 0.02 0.00 0.00 0.01
2019 1.42 0.00 0.00 0.00 0.00 0.04 0.36 0.57 0.37 0.08 0.00 0.00 0.01
2020 3.30 0.00 0.00 0.00 0.00 0.10 0.26 1.19 1.68 0.04 0.00 0.00 0.02
2021 2.61 0.01 0.00 0.00 0.00 0.05 0.25 1.59 0.52 0.11 0.00 0.00 0.07
2022 1.14 0.05 0.01 0.00 0.00 0.28 0.17 0.42 0.15 0.03 0.00 0.00 0.03
2023 1.33 0.00 0.00 0.00 0.00 0.02 0.25 0.81 0.17 0.05 0.00 0.00 0.03
2024 2.56 0.01 0.00 0.00 0.00 0.03 0.20 1.82 0.22 0.25 0.00 0.00 0.02
2025 0.68 0.00 0.00 0.00 0.00 0.01 0.01 0.62 0.02 0.02 0.00 0.00 0.00
2026 1.90 0.00 0.00 0.00 0.00 0.01 0.04 1.70 0.11 0.02 0.00 0.00 0.01
2027 1.37 0.03 0.00 0.00 0.00 0.05 0.05 1.14 0.05 0.02 0.00 0.00 0.02
2028 2.14 0.00 0.00 0.00 0.00 0.01 0.12 1.90 0.06 0.02 0.00 0.00 0.03
2029 3.46 0.00 0.00 0.00 0.00 0.01 0.21 3.12 0.05 0.03 0.00 0.00 0.03
2030 2.37 0.01 0.00 0.00 0.00 0.00 0.06 2.26 0.02 0.01 0.00 0.00 0.01
2031 6.06 0.00 0.00 0.00 0.00 0.00 0.05 5.97 0.03 0.00 0.00 0.00 0.01
2032 3.00 0.00 0.00 0.00 0.00 0.00 0.09 2.87 0.03 0.00 0.00 0.00 0.02
* With CBM@330 MW
Idaho Power Company State of Oregon IRP Guidelines
2013 Integrated Resource Plan—Appendix C Page 137
STATE OF OREGON IRP GUIDELINES

State of Oregon IRP Guidelines Idaho Power Company
Page 138 2013 Integrated Resource Plan—Appendix C

Idaho Power Company State of Oregon IRP Guidelines
2013 Integrated Resource Plan—Appendix C Page 139

State of Oregon IRP Guidelines Idaho Power Company
Page 140 2013 Integrated Resource Plan—Appendix C

Idaho Power Company State of Oregon IRP Guidelines
2013 Integrated Resource Plan—Appendix C Page 141

State of Oregon IRP Guidelines Idaho Power Company
Page 142 2013 Integrated Resource Plan—Appendix C

Idaho Power Company State of Oregon IRP Guidelines
2013 Integrated Resource Plan—Appendix C Page 143

State of Oregon IRP Guidelines Idaho Power Company
Page 144 2013 Integrated Resource Plan—Appendix C

Idaho Power Company State of Oregon IRP Guidelines
2013 Integrated Resource Plan—Appendix C Page 145
Compliance with State of Oregon IRP Guidelines
Oregon Order 07-047 Action Items 2013 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 25–36. Demand-side options for meeting the utility’s load are discussed in Chapter 4. Demand-Side Resources, pages 37–45.
a-2) Different resource alternatives results are compared in Chapter 7. Resource Alternatives Analysis, Table 7.1 on page 84. Different resource portfolios results are compared in Chapter 9. Modeling Analysis and Results, section Portfolio Costs, Table 9.2 on page 98.
a-3) The consistent modeling method for evaluating all resource alternatives is explained in Chapter 7. Resource Alternatives Analysis, pages 83-85. The consistent modeling method for evaluating all resource portfolios are explained in Chapter 9. Modeling Analysis and Results, pages 97–99.
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 97.
b-1) Electric utility risk and uncertainty factors (carbon, NG and water conditions) for resource alternatives are considered in Chapter 7. Resource Alternatives Analysis, section Risk Analysis and Results, pages 86–87.
Electric utility risk and uncertainty factors (load, carbon, NG and water conditions) for resource alternatives are considered in Chapter 9. Modeling Analysis and Results, section Stochastic Analysis, pages 103–105 (For electricity prices, AURORA forecasts electric market prices; therefore AURORA variables are changed to create different electric market price scenarios). An additional analysis for CO2 emissions costs can be found in the 2013 IRP Technical Appendix, section Regulatory Environmental Compliance Costs, page 131.
Note: Plant forced outages for resource alternatives and resource portfolios are not discussed in the IRP document or 2013 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 the following sections: FERC Relicensing, page 12; Idaho Water Issues, page 13;
Northwest Power Pool Energy Imbalance Market, page 17; and Federal Energy Legislation, page 19. Also, the uncertainty in transmission planning process is described in Chapter 6. Transmission Planning, pages 72–73.
A tipping-point analyses for carbon adder and dispatch cost is
analyzed in Chapter 5. Planning Period Forecasts, section Carbon Adder Generation Dispatch Analysis, pages 69–70.
c-1) The IRP methodology and its’ subsequent planning horizon of 20 years are discussed in Chapter 1. Summary, section IRP Methodology, fourth paragraph on page 4.
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 expected NPV for
resource alternative costs are found in Chapter 7. Resource Alternative Analysis, Table 7.1 on page 84. The summary of the expected NPV for total portfolio costs are found in Chapter 9. Modeling Analysis and Results, section Portfolio Costs, Table 9.2 on page 98.
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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 Analysis, pages 103–105. A plot of stochastic dispersion is shown in the 2013 IRP Technical Appendix, Stochastic Dispersion Plot on page 131.
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 resource choices appropriately balance cost and risk in a twofold process:
Identifying resources alternatives: discussed in Chapter 7. Resource Alternatives Analysis, pages 83–87.
For designing portfolios: discussed in Chapter 8. Planning Criteria and Portfolio Selection, pages 89–96.
d-1) The plan is consistent with long-run public interests and is
discussed in Chapter 2. Political, Regulatory, and Operational Issues, beginning pages 11–19 as well as 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 and 2013 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 2004, 2006, 2009, 2011 and 2013 IRPs. The IRP Advisory Council meetings are open to the public, on a limited basis due to space constraints. 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 2013 IRP, the 2013 Load and Sales Forecast and in the 2013 Technical Appendix.
As set forth in Guideline 2, part c., Idaho Power provided a draft 2013 IRP for public review on Friday, June 6, 2013, via a hard copy to members of IRP Advisory Committee and public attendees of the 2013 IRP Advisory Committee meetings. June 17, 2013 was the deadline for getting IRP Advisory Committee and public comments back on the draft plan.
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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 2011 IRP on May 21, 2012 in Order 12-177. Idaho Power plans to file the 2013 IRP on June 28, 2013.
b. Idaho Power will schedule a public meeting at the OPUC after the 2013 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 for EV. In ORDER NO. 12-177, the OPUC noted 12 action items regarding Idaho Power’s 2011 IRP. Idaho Power has addressed these action items in the 2013 IRP.
f. Idaho Power submitted an update to the 2011 IRP in February 2013.
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 5. Planning Period Forecasts, section Load Forecast, beginning on page 47. High- and low-growth scenarios in addition to stochastic load risk analysis are discussed in Chapter 9. Modeling Analysis and Results, section Stochastic Analysis, pages 103–105.
c. Peaking capacity and energy capability for each year of the plan are discussed in Chapter 5. Planning Period Forecasts, sections Average Monthly Energy Planning and Peak-Hour Planning, pages 60–61. 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 80.
d. Not applicable.
e. Supply-side resources and their levelized costs and technologies are covered in Chapter 5. Planning Period Forecasts on figures 5.7 and 5.8, pages 66 and 67 respectively. Demand-side resources and their levelized costs and technologies are covered in Chapter 4. Demand-Side Resources, in Table 4.2 on page 43.
f. Resource reliability is covered in Chapter 9. Modeling Analysis and Results, section Loss of Load Expectation, on pages 110111.
g. Fuel price forecasts are discussed in Chapter 5. Planning Period Forecasts, section Coal Resources (coal price forecast and environmental compliance cost analysis), pages 5859, section Natural Gas Price Forecast, on page 62. Environmental compliance costs are also discussed in section Emissions Adders for Fossil Fuel-Based Resources, pages 63–64. Alternative scenarios are considered in Chapter 9. Modeling Analysis and Results, section Stochastic Analysis,
pages 103–105.
h. Construction of resource portfolios are made in a twofold process:
1) Identifying resources alternatives: discussed in Chapter 7. Resource Alternatives Analysis, pages 83–87. 2) For designing
portfolios: discussed in Chapter 8. Planning Criteria and Portfolio Selection, pages 89–96.
i. The resource portfolios are evaluated against various risks in Chapter 9. Modeling Analysis and Results, section Stochastic Analysis, pages 103–105.
j. The portfolios are evaluated and ranked in Chapter 9. Modeling Analysis and Results, Table 9.2 on page 98.
k. The uncertainties associated with each portfolio are evaluated in Chapter 9. Modeling Analysis and Results, section Stochastic
Analysis, pages 103–105.
l. The selection reasoning for the preferred resource portfolio is identified in Chapter 9. Modeling Analysis and Results, Table 9.2 on page 98 and Figure 9.6 on page 104.
m. No inconsistencies were identified.
n. An annual near-term action plan is described in Chapter 1. Summary, section Near-Term Action Plan, starting on page 9.
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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 2013 IRP Technical Appendix, section Transmission Cost Assumptions on page 86. The transmission required for each resource portfolio being considered is also described in Chapter 6. Transmission Planning, section Transmission Assumptions in the IRP
Portfolios, pages 80–81. AURORA accounts for the cost of wheeling when selling and purchasing power from the market. Transmission facilities were analyzed as a resource option in Chapter 7. Resource Alternatives Analysis, pages 83–84. All the resource portfolios contained the Boardman to Hemingway Transmission Line as a
resource option as discussed in Chapter 8. Planning Criteria and Portfolio Selection, pages 89–96.
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. Idaho Power periodically studies conservation potential and a summary of the company’s conservation (DSM) philosophy is described in Chapter 4. Demand-Side Resources, pages 37–38.
b. Cost-effectiveness of energy efficiency programs are detailed in Chapter 4. Demand-Side Resources, section Demand Response Performances, pages 38–44.
c. As described in Chapter 4. Demand-Side Resources, third paragraph of page 37, due to the indirect nature of savings
from regional market transformation activities, Idaho Power’s outside party administrator Northwest Energy Efficiency Alliance (NEEA) impacts are not accounted for in the 2013 IRP.
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 Resources on page 44.
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.
Idaho Power discusses the regulatory compliance costs they expect for carbon dioxide (CO2), nitrogen oxides, sulfur oxides, and mercury emissions in Chapter 5. Planning Period Forecasts, section Emission Adder for Fossil Fuel-Based Resources, pages 63–64. The costs are shown in the 2013 IRP Technical Appendix, section Environmental Compliance Costs beginning on page 131.
Idaho Power performed a base case, upper case, and zero-cost case and for the compliance cost of CO2 and is discussed in Chapter 5. Planning Period Forecasts, section Carbon Adder, pages 68–69.
Idaho Power discusses the sensitivity analysis on a range of reasonably possible cost adders (low and high case) for nitrogen oxides, sulfur oxides, and mercury emissions in Chapter 5. Planning Period Forecasts, section Emission Adder for Fossil Fuel-Based Resources on page 64. The costs are shown in 2013 IRP
Technical Appendix, section Environmental Compliance Costs beginning on page 131.
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 2013 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 2013 IRP in both the Idaho and Oregon jurisdictions.
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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, pages 106–108, and the loss of load probability in Chapter 9. Modeling Analysis and Results, section Loss of Load Expectation, pages 110–111.
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 generation technologies in the following sections:
Load shed, grid sync, and distributed PV: in Chapter 5. Planning Period Forecasts, Figure 5.7 and 5.8, pages 66 and
67, respectively.
Distributed PV: in Chapter 7. Resource Alternatives, pages 83–87.
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 06-446 issued on August 10, 2006.
Idaho Power discussed asset ownership in Chapter 10 Action Plan, section Acton Plan (2013–2032), last paragraph on page 114.
In the next 10 years, the Boardman to Hemingway Transmission Line is the only new IRP resource identified. Idaho Power is currently
permitting this project and plans to contract the construction work.

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Compliance with EV Guidelines
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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;
Forecasting the balancing reserves needed at different time intervals to respond to variation in load and intermittent renewable generation is discussed in Chapter 9. Modeling Analysis, section Flexible
Resource Needs Assessment, pages 109–110.
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;
Forecasting the balancing reserves available at different time intervals from existing generating resources is discussed in
Chapter 9. Modeling Analysis, section Flexible Resource Needs Assessment, pages 109–110.
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.
Evaluating all resource options, including the use of EVs, is discussed in Chapter 9. Modeling Analysis, section Flexible
Resource Needs Assessment, pages 109–110.

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Compliance with State of Oregon Action Items Regarding
Idaho Power’s 2011 IRP
Oregon Order 12-177 Action Items 2013 IRP
Action Item 1: Evaluation of Environmental Compliance Costs for Existing Coal-Fired Plants (Action Item 11)
Idaho Power does not wholly own or operate any coal plants, but does have a significant ownership interest in three large plants (Boardman, North Valmy, and Jim Bridger). As reported by CUB, these plants provide 41 percent of Idaho Power's
total generation.
CUB points out that the owners of these three plants likely will face increasing costs to comply with clean air regulations in the coming years. CUB and RNP are not satisfied with Idaho Power's analysis of the possible environmental compliance
costs associated with ownership and operation of these plants. CUB suggests that Idaho Power be required to conduct a unit-by-unit evaluation of its clean air investment costs (similar to that conducted by PGE for its Boardman plant) before the IRP provisions relating to coal plant investment are considered for
acknowledgement. CUB recommends that the Commission withhold acknowledgment of the IRP until Idaho Power completes a study of its coal investment compliance costs and the parties have had the opportunity to review and comment on the study. RNP also recommends that the Commission require
Idaho Power to analyze the costs and risks of maintaining its coal plants (including carbon costs and environmental regulations) before the company commits to significant investments.
Idaho Power responds that because the amount of any
environmental compliance costs is "highly speculative" at this time, any analysis of the costs would be highly speculative as well. The company argues that the Commission should acknowledge its 2011 IRP, and require that Idaho Power conduct the environmental costs analysis in future IRP filings.
Staff shares CUB's and RNP 's concerns about future environmental compliance costs, but agrees with Idaho Power that the company should provide the requested analysis in its 2011 IRP Update. Staff proposes an additional Action Item 11 to address this future requirement.
Idaho Power performed an evaluation of environmental compliance costs for existing coal-fired plants in the Coal Unit Environmental Investment Analysis for the Jim Bridger and North Valmy Coal-Fired Power Plants (the coal study excludes the Boardman Plant in Oregon that is scheduled to cease coal-fired operations at the end of 2020). Idaho Power filed the report with the IPUC and OPUC in
February 2013 as part of the 2011 Integrated Resource Plan Update.
In the 2013 IRP, Idaho Power analyzed two portfolios where the company exited from both Jim Bridger and North Valmy coal-fired generating facilities. Idaho Power also analyzed two portfolios where the company exited from North Valmy coal-fired generating facility on
the schedule announced by NV Energy. The results of the analysis can be found in Chapter 9. Modeling Analysis and Results, Table 9.2 on page 98.
Action Item 2: Boardman to Hemingway Transmission (Action Item 7)
RNP supports acknowledgment of the Boardman to Hemingway (B2H) transmission project as the primary resource in Idaho Power's near-term portfolio. Staff recommends we acknowledge Action Item 7 requiring Idaho Power to continue to make progress on the B2H transmission project between now and the completion of the company's 2013IRP. CUB notes, however, that closure of one or more coal plants would open up capacity on existing transmission lines and could cause changes to the
design and location of new lines.
Idaho Power analyzed Boardman to Hemingway as uncommitted resource in two ways:
1) Resource Alternatives: eight resources were analyzed side-by-side to achieve a 200-MW capacity of peak-hour contribution. The Resource Alternatives analysis can be found in Chapter 7. Resource Alternative Analysis, pages 83–87.
2) Resource Portfolios: Boardman to Hemingway was in all nine portfolios. The results of the Resource Portfolio analysis can be found in Chapter 9. Modeling Analysis and Results, Table 9.2 on page 98.
Progress on Boardman to Hemingway was discussed in the
Boardman to Hemingway section of Chapter 6. Transmission Planning, pages 77–78.
Action Item 3: Conservation Voltage Reduction (Action Item 4)
Staff notes the ''promising beginnings" for conservation voltage reduction (CVR) measures reported by Idaho Power. Staff points out, however, that the Company shows no further CVR measures in either its IRP or its Appendix B on Demand-Side Management. We are convinced that there is an untapped CVR resource and that this resource is cost effective. We direct the addition of a CVR action item as follows:
Action Item 4 - Conservation Voltage Reduction- 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 plan 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.
Idaho Power included an assessment of the available cost-effective CVR resource potential in its service area. This can be found in the Conservation Voltage Reduction section of Chapter 4 Demand-Side
Resources on page 45.
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Action Item 4: Demand Response (Action Item 3)
In this IRP cycle Idaho Power switched from an "all cost-effective DSM" approach to "need-based" approach. Based on its analysis comparing the costs of energy saved from demand response to the cost of owning and operating a simple cycle
combustion turbine (SCCT), Idaho Power derived an optimal amount of demand response for its system. Staff believes that the Company should pursue all cost-effective demand response through existing programs and consider new programs as applicable. Staff believes Idaho Power should pursue the
maximum amount of demand response that (1) is less costly on a kW basis than a supply-side resource, and (2) up to the company's system capacity deficit amount.
Chapter 4. Demand-Side Resources, pages 37–45. provides a detailed discussion and analysis of the company’s DSM programs. All nine resource portfolios include Demand Response. Resource portfolios are described in the Portfolio Design and Selection section of Chapter 8. Planning Criteria And Portfolio Selection, pages 90–96.
Action Item 5: Energy Efficiency (Action Items 1 and 2)
Staff recommends acknowledgment of Idaho Power's Action
Items 1 and 2, and recommends the Company continue to pursue all cost-effective demand side management as the lowest cost resource for customers.
Energy efficiency performance is discussed in Chapter 4 Demand-Side Resources, section Energy Efficiency Performance,
pages 38-39. New energy efficiency programs are discussed in Chapter 4 Demand-Side Resources, section New Energy Efficiency Resources, pages 41-44.
Action Item 6: Alternative Portfolio (Action Items 8 and 9)
RNP urges the Commission to consider alternatives to
acknowledging Idaho Power's alternative resource portfolio (which is comprised solely of SCCT plants). RNP recommends the Commission give demand side management and solar photovoltaic resources time to ripen. Staff recommends the Commission not acknowledge the alternative portfolio, because
there are existing mechanisms in the IRP process to deal with unforeseen circumstances.
Eight resources, including four renewable resources, were analyzed side-by-side to achieve 200 MW of peak-hour contribution. The analysis can be found in Chapter 7. Resource Alternative Analysis, pages 83–87.
Four resource portfolios were constructed where Idaho Power ceased operations at some or all of the Idaho Power coal-fired generation facilities. One of the portfolios was jointly designed by the Idaho Conservation League and Boise State University. Portfolio design is discussed in the Portfolio Design and Selection section of Chapter 8. Planning, pages 90–96.
Action Item 7: Long Term Action Items (Action Item 12)
In its Action Plan, Idaho Power included action items for the
2021 through 2030 time period. Because the IRP Guidelines focus on actions over the next two to four years, Staff recommends that these long-term action items not be acknowledged as part of this IRP.
Idaho Power provides its action plan in Chapter 10. Action Plan, pages 113–115.
Action Item 8: Load Forecast
Staff is concerned that Idaho Power's assumptions of average energy growth and peak-hour load growth are too high. Staffs concerns are based on the lingering economic conditions, plus shifts occurring in the demand/supply balance, conservation, and environmental regulation.
Idaho Power’s load forecast is discussed in detail in Chapter 5. Planning Period Forecasts, section Load Forecast, pages 47–55. Lingering economic conditions are discussed in detail, pages 48–50.
Action Item 9: Risk Analysis
Staff is troubled by aspects of Idaho Power's stochastic risk analyses, as contrasted with the more conventional approaches used by other Oregon utilities. With the approach used by Idaho Power, an adverse combination of two or more unfavorable risk factors will never be "sampled," because only one risk factor is allowed to depart from its base value for any one "draw." Staff also recommends the company include hydro generation variability as a risk factor for its next IRP cycle, in light of Idaho Power's significant reliance on hydroelectric generation.
Idaho Power incorporated hydro generation variability as a risk factor. Idaho Power also used the AURORA model to perform stochastic risk analyses. Stochastic analysis is discussed in the Stochastic Analysis section of Chapter 9. Modeling Analysis and Results, pages 103–105.
Action Item 10: Wind Integration Study
RNP noted that Idaho Power is conducting a wind integration study internally. It encouraged the company to look for ways to lower its costs of wind integration, to seek independent technical
review of its study, and to provide stakeholders the chance to provide meaningful feedback.
Idaho Power filed a wind integration study in February 2013. The wind integration study included an independent technical review. The wind integration study can be found on the Idaho Power website:
www.idahopower.com/pdfs/AboutUs/PlanningForFuture/irp/
2013/windIntegrationStudy.pdf
Action Item 11: Solar Photovoltaic Analysis
RNP encourages Idaho Power to evaluate the performance of solar photovoltaic projects as a class, not simply as single projects. The geographic distribution of the projects could have a significant effect of smoothing the short-term variability of single projects.
Idaho Power evaluated the performance of solar PV generation as a class. The PV analysis can be found in Chapter 7. Resource Alternative Analysis, pages 83–87.
Idaho Power Company State of Oregon Action Items Regarding Idaho Power’s 2011 IRP
2013 Integrated Resource Plan—Appendix C Page 167
Oregon Order 12-177 Action Items 2013 IRP
Action Item 12: Adherence of Plan to Integrated Resource Planning Guidelines
Intervenors and Staff agree that Idaho Power's 2011 IRP filing did not comply with IRP Guidelines 1 (c) and 4(g), 4 because the company failed to provide a comprehensive evaluation of the
compliance of its existing coal fired generation resources with new, draft, and anticipated environmental regulations. Without that evaluation, it was not possible to determine whether any of the candidate resource portfolios met the specified standard.
In response to that deficiency, in its September 20, 2011 IRP
presentation to the Commission, Idaho Power presented a "very high-level" evaluation of a range of costs that could potentially result if certain environmental regulations were implemented.
According to the company, the existing coal-fired resources would still be less expensive than replacement natural gas
generation resources, even if the company were required to spend the estimated amounts to comply with the potential federal environmental regulations.
Staff also noted that Idaho Power did not comply with IRP Guidelines 4(a) and 4(n), because the company did not explain
how the utility met each substantive and procedural requirement, nor provide a concise listing of action items for all resources and resource related activities.
Idaho Power performed an evaluation of environmental compliance costs for existing coal-fired plants in the Coal Unit Environmental Investment Analysis for the Jim Bridger and North Valmy Coal-Fired Power Plants (the coal study excludes the Boardman plant in Oregon which is scheduled to cease coal-fired operations at the end of 2020). Idaho Power filed the report with the IPUC and OPUC in February 2013 as part of the 2011 Integrated Resource Plan Update.
In the 2013 IRP, Idaho Power analyzed two portfolios where the company exited from both Jim Bridger and North Valmy coal-fired generating facilities. Idaho Power also analyzed two portfolios where the company exited from North Valmy coal-fired generating facility on the schedule announced by NV Energy. The results of the analysis can be found in Chapter 9. Modeling Analysis and Results, Table 9.2 on page 98.The OPUC is currently reviewing the Idaho Power coal study as part of Oregon Docket No. LC 57.
1. Idaho Power provides a concise listing of action items in Chapter 10. Action Plan, pages 113–114.

State of Oregon Action Items Regarding Idaho Power’s 2011 IRP Idaho Power Company
Page 168 2013 Integrated Resource Plan—Appendix C
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