20250213Attachment - 2025 Wildfire Mitigation Plan.pdf

WILDFI
MITIGATIOI�
PLAN
V
HIQAW POMRO
©2024 Idaho Power

Idaho Power Company Wildfire Mitigation Plan 2025
Table of Contents
Tableof Contents...........................................................................................................................i
Listof Tables .................................................................................................................................v
Listof Figures...............................................................................................................................vi
Listof Appendices........................................................................................................................ ix
ExecutiveSummary....................................................................................................................... 1
WMP Approach and Progress ................................................................................................. 1
Mitigating Wildfire Risk.....................................................................................................2
2024 Wildfire Mitigation Goals and Accomplishments .....................................................3
Customer Communications and Outreach ...................................................................... 11
Key Takeaways and Lessons Learned from 2024.............................................................12
RegulatoryContext .....................................................................................................................16
1. Introduction ............................................................................................................................17
1.1. Background ....................................................................................................................17
1.2. Idaho Power Profile and Service Area ............................................................................17
1.3. Asset Overview...............................................................................................................19
1.4. Objectives of this Wildfire Mitigation Plan.....................................................................20
1.5. Wildfire Mitigation Plan Maturity ..................................................................................20
2. Government, Industry, and Peer Utility Engagement..............................................................24
2.1. Objective........................................................................................................................24
2.2. Government Engagement ..............................................................................................24
2.3. Industry and Peer Utility Engagement............................................................................25
3. Quantifying Wildland Fire Risk................................................................................................33
3.1. Objective........................................................................................................................33
3.2. Identifying Areas of Elevated Wildfire Risk.....................................................................33
3.2.1. Wildfire Risk Modeling Process .............................................................................34
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Wildfire Mitigation Plan 2025 Idaho Power Company
3.2.2. Establishing Wildfire Risk Zones ............................................................................35
3.3. Wildfire Risk Zones.........................................................................................................37
3.3.1. Maps......................................................................................................................41
3.3.2. Boardman to Hemingway Proposed Transmission Line.........................................54
4. Mitigation Approach ...............................................................................................................55
4.1. Objective........................................................................................................................55
4.2. Risk-Based Cost and Benefit Analysis of Wildfire Mitigation..........................................55
4.3. Risk Analysis and Drivers................................................................................................57
4.3.1. Probabilistic Risk Modeling....................................................................................59
4.4. Wildfire Mitigation Cost Summary.................................................................................60
4.5. Wildfire Mitigation Activities..........................................................................................64
4.5.1. Quantifying Wildland Fire Risk...............................................................................65
4.5.2. Situational Awareness—Weather Forecasting Activities and Personnel ...............66
4.5.3. Situational Awareness—Advanced Technologies..................................................67
4.5.4. Field Personnel Practices.......................................................................................68
4.5.5. Transmission and Distribution (T&D) Programs for Wildfire Mitigation................69
4.5.6. Enhanced Vegetation Management......................................................................73
4.5.7. Communications and Information Technology Customer
Notification Enhancements .................................................................................74
4.5.8. PSPS Emergency Preparedness and Technology....................................................75
4.5.9. Incremental Capital Investments...........................................................................76
5. Situational Awareness.............................................................................................................82
5.1. Overview........................................................................................................................82
5.2. Fire Potential Index ........................................................................................................82
5.3. FPI Review and Evaluation..............................................................................................84
5.4. Forecast Ensemble .........................................................................................................84
6. Mitigation—Field Personnel Practices ....................................................................................85
6.1. Overview........................................................................................................................85
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Idaho Power Company Wildfire Mitigation Plan 2025
6.2. Wildland Fire Preparedness and Prevention Plan...........................................................85
7. Mitigation—Operations ..........................................................................................................86
7.1. Overview........................................................................................................................86
7.2. Operational Protection Strategy Definitions ..................................................................86
7.3. Transmission Line Operational Strategy.........................................................................87
7.3.1. Fire Season Temporary Operating Procedure for Transmission Lines 115
kilovolt (kV) &Above...........................................................................................87
7.3.2. Tier 3 Zone Transmission Operational Strategy 69 kV & Below.............................87
7.4. Distribution Operational Strategy and EPS.....................................................................87
7.5. PSPS................................................................................................................................88
7.5.1. PSPS Definition ......................................................................................................88
7.5.2. PSPS Plan...............................................................................................................89
8. Asset Management and Inspection Initiatives ........................................................................90
8.1. Overview........................................................................................................................90
8.2. T&D Asset Management and Inspections.......................................................................90
8.3. Inspection and Correction Timeframes ..........................................................................91
8.4. Transmission Asset Management and Inspection Initiatives..........................................92
8.4.1. Aerial Visual Inspection Program...........................................................................92
8.4.2. Ground Visual Inspection Program........................................................................93
8.4.3. Detailed Visual (High-resolution Photography) Inspection Program .....................93
8.4.4. Thermal Imaging (Infrared) Inspections.................................................................93
8.4.5. Wood Pole Inspection and Treatment Program ....................................................93
8.4.6. Cathodic Protection and Inspection Program........................................................94
8.4.7. Transmission Asset Protection ..............................................................................94
8.5. Distribution Asset Management and Inspection Initiatives.......................................... 100
8.5.1. Ground Visual Inspection .................................................................................... 100
8.5.2. Line Equipment Inspection Program ................................................................... 100
8.5.3. Thermal Imaging (Infrared) Inspections............................................................... 100
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Wildfire Mitigation Plan 2025 Idaho Power Company
8.5.4. Wood Pole Inspection and Treatment Program .................................................. 101
8.5.5. Overhead Primary Hardening Program ............................................................... 101
8.6. Ignition Tracking and Analysis...................................................................................... 103
8.6.1. Root Cause Analysis............................................................................................. 104
8.7. Vegetation Management ............................................................................................. 104
8.7.1. Overview ............................................................................................................. 104
8.7.2. Program Components ......................................................................................... 105
8.7.3. Vegetation Management Definitions .................................................................. 106
8.7.4. Transmission Vegetation Inspection and Management ...................................... 107
8.7.5. Distribution Vegetation Management................................................................. 108
8.7.6. Pole Clearing of Vegetation................................................................................. 109
9. Wildfire Response................................................................................................................. 111
9.1. Overview...................................................................................................................... 111
9.2 Emergency De-energization .......................................................................................... 111
9.3 Response to Active Wildfires......................................................................................... 111
9.4. Restoration of Electrical Service................................................................................... 112
9.4.1. Mutual Assistance ............................................................................................... 112
9.5. Public Outreach and Communications ......................................................................... 112
10. Communicating About Wildfire........................................................................................... 113
10.1. Objective.................................................................................................................... 113
10.2. Community Engagement............................................................................................ 113
10.3 Community Resource Centers..................................................................................... 116
10.4. Customer Communications........................................................................................ 117
10.4.1. Key Communication Methods ........................................................................... 117
10.4.2. Timing of Outreach............................................................................................ 128
10.4.3. Communication Metrics.................................................................................... 128
10.4.4. Customer Feedback........................................................................................... 131
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Idaho Power Company Wildfire Mitigation Plan 2025
10.5. Idaho Power Internal Communications—Employees................................................. 133
11. Performance Monitoring and Metrics................................................................................. 134
11.1. Wildfire Mitigation Plan Compliance.......................................................................... 134
11.2. Internal Audit ............................................................................................................. 134
11.3. Annual Review............................................................................................................ 134
11.4. Wildfire Risk Map....................................................................................................... 134
11.5. Situational Awareness................................................................................................ 134
11.6. Wildfire Mitigation—Field Personnel Practices.......................................................... 135
11.7. Wildfire Mitigation—Operations................................................................................ 135
11.8. Wildfire Mitigation—T&D Programs .......................................................................... 135
11.9. Long-term Metrics...................................................................................................... 138
List of Tables
Table 1
Grid hardening and situational awareness.................................................................................3
Table 2
Inspection and Vegetation Management program summary.....................................................7
Table 3
Overhead transmission voltage level and approximate line mileage by state*........................19
Table 4
Idaho Power IWRMC maturation approach .............................................................................23
Table 5
2025 risk zone changes ............................................................................................................37
Table 6
Idaho Power's overhead transmission and distribution lines by risk zone in Idaho and
Oregon* ...................................................................................................................................40
Table 7
CAL FIRE wildfire data by year..................................................................................................56
Table 8
Estimated system-wide O&M expenses for wildfire mitigation, $000s (2024-2029)*.............61
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Wildfire Mitigation Plan 2025 Idaho Power Company
Table 9
Safety, reliability, and resilience co-benefits of wildfire mitigation initiatives.........................64
Table 10
WMP forecasted capital investments.......................................................................................77
Table 11
Asset management and inspection initiatives..........................................................................90
Table 12
Service area asset overview .....................................................................................................91
Table 13
Summary of asset inspections and schedules by state and zone .............................................92
Table 14
Transmission line rebuild projects, estimated planned investment ($000s) and timeline .......96
Table 15
Vegetation Management Program summary......................................................................... 105
Table 16
Summary of vegetation management activities and schedules ............................................. 106
Table 17
Idaho Power community engagement, 2024 ......................................................................... 114
Table 18
Key communication metrics................................................................................................... 130
Table 19
T&D programs metrics ........................................................................................................... 136
Table 20
Outagemetrics....................................................................................................................... 138
Table 21
Overhead circuit hardening reliability improvements............................................................ 139
List of Figures
Figure 1
Approach to wildfire mitigation .................................................................................................2
Figure 2
Idaho Power service area.........................................................................................................18
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Idaho Power Company Wildfire Mitigation Plan 2025
Figure 3
WMP development in western investor-owned electric utilities.............................................21
Figure 4
IWRMC Maturity Model Matrix................................................................................................22
Figure 5
Discussion of Enhanced Protection Settings (EPS) with peer utilities at PG&E.........................25
Figure 6
Wildfire risk-based methodology.............................................................................................33
Figure 7
Risk zone evaluation and determination process.....................................................................36
Figure 8
Southern Region —2025 wildfire risk zone additions ...............................................................38
Figure 9
Western Region —2025 wildfire risk zone additions ................................................................39
Figure 10
Idaho Power wildfire risk zones................................................................................................42
Figure 11
Eastern Idaho—Pocatello area...................................................................................................43
Figure 12
Eastern Region—Salmon area....................................................................................................44
Figure 13
Southern Region—Wood River Valley .......................................................................................45
Figure 14
Southern Region—Pine-Featherville..........................................................................................46
Figure 15
CapitalRegion—Boise Front ......................................................................................................47
Figure 16
Centerville................................................................................................................................48
Figure 17
IdahoCity area .........................................................................................................................49
Figure 18
Cascade/Donnelly area.............................................................................................................50
Figure 19
Garden Valley/Crouch area......................................................................................................51
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Wildfire Mitigation Plan 2025 Idaho Power Company
Figure 20
McCall/New Meadows area.....................................................................................................52
Figure 21
HalfwayOregon........................................................................................................................53
Figure 22
Proposed132H route.................................................................................................................54
Figure 23
Idaho Power WMP risk management framework....................................................................57
Figure 24
Riskbow-tie diagram................................................................................................................58
Figure 25
May 2024 issue of Connections.............................................................................................. 119
Figure 26
Idaho Power developed an educational video on PSPS events. ............................................. 120
Figure 27
Customeremail, May 2024 .................................................................................................... 121
Figure 28
Postcard to customer living in a WRZ..................................................................................... 122
Figure 29
Example social media posts.................................................................................................... 123
Figure 30
Postcard to customer Idaho Power could not reach with contact information on file........... 124
Figure 31
Julybill insert.......................................................................................................................... 125
Figure 32
Idaho Power's wildfire safety landing webpage..................................................................... 126
Figure 33
Idaho Power digital ad, summer 2024.................................................................................... 127
Figure 34
Idaho Power PSPS flyer .......................................................................................................... 128
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Idaho Power Company Wildfire Mitigation Plan 2025
List of Appendices
Appendix A
Wildland Fire Preparedness and Prevention Plan
Appendix B
Public Safety Power Shutoff(PSPS) Plan
Appendix C
Wildfire risk zone map book
Appendix D
Oregon wildfire requirements and recommendations
Page ix

Oxecut *ive Surw%
Idaho Power is dedicated to the safety of its customers and
communities, and to safely delivering reliable, affordable
energy.The company's Wildfire Mitigation Plan (WMP)
constantly evolves in pursuit of that mission.
Idaho Power's WMP provides holistic and prudent strategies
to improve safety, reliability, and affordability for our
customers and the communities we serve. Its purpose
is to guide mitigation strategies and reduce risk.
The 2025 WMP is Idaho Power's fifth annual edition of this
document. It includes:
- Descriptions of Idaho Power's efforts to protect, or "harden,"
the grid against wildfires and other natural emergencies
Maps of wildfire risk zones across our service area
An explanation of our Fire Potential Index (FPI), including how
it was developed and is being implemented
Descriptions of work being done to protect our power lines
from trees and other vegetation
•A description of our Public Safety Power Shutoff(PSPS) plan
Throughout 2024, Idaho Power worked to reduce wildfire
risk by hardening our electrical system, expanding situational
awareness capabilities, further enhancing our vegetation
management programs, and upgrading our risk modeling
practices.The company also spent significant resources
responding to damage caused by dozens of wildfires across
our service area.
' In this Executive Summary, we provide a comprehensive
overview of the 2024 wildfire season, lessons learned from it,
and a snapshot of our progress toward system-wide wildfire
mitigation objectives.
WMP Approach and Progress
Idaho Power's WMP prioritizes the safety of the customers and ,
.�� communities we serve and supports the resiliency of Idaho
} •.�;; Power's transmission and distribution (T&D) system.
WMIR S fUnQamental gvais are t4
• Reduce wildfire risk associated with the company's T&D
equipment and related field operations.
Improve the resiliency of Idaho Power's T&D system in
a wildfire event, independent of the ignition source.
Pagel

Mitigating Wildfire Risk
Idaho Power deploys a variety of wildfire risk mitigation activities through its WMP.As displayed
in Figure 1, the company's strategy to reduce wildfire risk is multi-pronged and involves activities
and actions to: 1) reduce the likelihood of wildfire, 2) reduce the intensity of wildfire, and 3) reduce
susceptibility to wildfire.
Reducing the likelihood of wildfire primarily involves efforts like overhead circuit hardening,
undergrounding, enhanced vegetation management and situational awareness through deployment
of fire weather station networks, and advanced risk modeling.These are identified and adopted based
on a variety of factors, including industry best practices for reducing wildland fire risk, evaluation of
inherent risk across the service area, and with consideration of alternatives.
To reduce susceptibility to wildfires, Idaho Power focuses on education and communication, specifically
engagement with government agencies, industry entities, expert forums, public safety partners, and
electric utility peers to build our understanding of wildfire risk and commonality of wildfire mitigation
plans. Simultaneously, the company uses historical climatology and climate projections to identify
current and potential changes in future fire risk. In addition, Idaho Power adds protective mesh to
wood transmission poles to protect the poles from wildfire—specifically in wildfire risk zones or
areas prone to wildfire.
Finally, to reduce the intensity of wildfire, Idaho Power works to reduce the amount of available fuel
that can burn.These efforts include fuel reduction partnerships and pole clearing. Idaho Power is
also piloting a program for deploying wildfire detection cameras that can improve the speed and
effectiveness of response to wildfires.
Feeder Hardening
Asset Inspections
Vegetation Management Fuel Reduction — Shared Stewardship
Protection Changes Pole Clearing
Proactive De-energization a' � Wildfire Detection Cameras
Underground Conversions rOp
Fire W ea �j� Vegetation Management
theS r tations �p
v 'L
Wildfire Risk
Susceptibility
Public Meetings
Education and Preparedness
Partnering with Fire Agencies and Firewise
Fire Mesh Wrap
Climatology

2024 Wildfire Mitigation Goals and Accomplishments
Each year, Idaho Power develops high-level goals associated with its WMP. Idaho Power met or exceeded
the established goals for 2024.
Table 1
Grid hardening and situational awareness
024 2024 2024
System Completed Completed Total% Planned Planned
Initiative Wildfire Mitigation Plan Activities o. O• O•
Distribution System Hardening
System System Hardening(miles) 75 80 4 112% 85 5
Hardening* Overhead Line Miles Converted — — — 100% 2 —
to Underground
Segmentation Devices
Feeder Installation or Relocation of 25 33 9 168% 41 3
Segmentation Automatic Reclosing Devices
Transmission Fire Mesh Installation
Fire Resistant Number of Poles Protected 700 701 90 113% 648 56
Mesh
Situational Awareness
Situational Weather Station Installation 5 4 1 100% 80 5
Awareness Wildfire Detection Camera 6 6 — 100% 2 1
Site Establishment**
*Excludes hardening work outside of wildfire risk zones
**Idaho Power collaborates with federal,state,and local agencies to identify and establish wildfire detection camera sites.The Bureau of Land Management(BLM)Idaho established
one of the sites Idaho Power planned to establish in 2024.
T
, ,

• ' r
f c
ADDITIONAL
r
Grid Hardeningline miles in 2025
Idaho Power's grid hardening program
includes systematic replacement of
= ' hardware, equipment, and materials .,
to improve safety and reliability
and provide for additional wildfire
protections.The 2024 grid hardening
program resulted in the hardening of
84 line miles in Tier 3 wildfire risk zones
1 across the company's service area.
01
Idaho Power plans to harden an
additional 90 line miles in 2025.
Z
Feeder Segmentation
Segmentation is a strategy that isolates portions of feeders in areas of higher wildfire risk from
areas of lower risk, improving reliability for customers outside wildfire risk zones and, in the
event of an outage, expediting restoration. Segmentation is most efficiently accomplished through
remote-controlled devices instead of manual adjustments performed in the field.
In 2024, as part of our work to isolate circuit segments, Idaho Power installed 42 automatic reclosing
(AR) devices (reclosers), upgraded 10 controllers, and upgraded remote communication capabilities
for 74 AR devices in wildfire risk zones.This work, along with communication upgrades to existing
reclosers, decreased PSPS impacts for approximately 70,000 customers.
In 2025, Idaho Power plans to complete approximately 44 automatic recloser installations or
upgrades throughout its service area to improve remote communication capabilities to distant
segmentation devices.
Page 4

Strategic Undergrounding
Idaho Power uses strategic undergrounding as a wildfire mitigation strategy
in Tier 3 Zones. Strategic undergrounding enhances the distribution system's
IF resiliency by burying targeted powerlines.This reduces the risk of wildfires.
In 2024, the company identified seven miles of overhead powerlines for
underground conversion through 2026 and began developing designs.
Underground conversion projects require extensive planning for trenching,
boring, and route optimization.The design phase also considers geological
permitting challenges, such as securing permits and coordinating with local
IF agencies,which can significantly lengthen timelines.The company prioritizes
candidate circuits or portions of circuits for underground conversion by
considering the following:
•Wildfire risk modeling and quantification, showing areas with elevated
risk of wildfire spread and impacts to people and property
IF • Fire history where overhead powerlines may be susceptible to repeated
wildfire events over their lifetime
•Areas with minimal egress or evacuation routes
•Areas with limited ingress or fire suppression resources
• Circuits with a higher likelihood of experiencing a fault due to external
IF conditions, such as lightning or contact from a tree that falls into the powerline
•Areas with historic weather patterns that increase the potential of repeated
PSPS events
•Areas in wildfire risk zones that have limited access or present difficulties
in performing inspections or maintenance
• Feedback from local officials or fire agencies on topography and fuels in
areas conducive to rapid fire spread that may impact highly valued resources,
watersheds, or critical facilities
Fire-Resistant
Mesh Installation
To improve the resiliency . Idaho
'•wer's transmission system, thepcompany wraps wood transmission
oles in •fire risk zone
fire-resistant mesh.The mesh wrap
helps protect the integrity of the pole
if it is exposed • wildfire. 1
791 poles were wrapped
across Idaho Power'sservice area.An additional 704 poles
are scheduled to •- wrapped in 2025.

r
4
Situational Awareness
Fire Weather Stations: Idaho Power's Atmospheric Sciences
department uses high-resolution modeling and forecasting
capabilities, combined with existing fire weather stations and
publicly available weather and fuel data, to develop and circulate
daily FPI forecasts.This information informs field personnel practices
and operational settings during days with increased fire potential.
FPI forecasts are also used in conjunction with Idaho Power's
weather forecasting efforts to detect extreme weather events that
may trigger a PSPS. Idaho Power installed five fire weather stations
in Tier 3 wildfire risk zones in 2024 and plans to install approximately
85 additional fire weather stations in or
near tier 2 and 3 zones in 2025.
Wildfire Detection Cameras: Idaho Power works with
ALERTWest to install wildfire detection cameras. Firefighting
agencies and Idaho Power can use the camera feeds to quickly
detect wildfire, track real-time weather and fuel conditions, and
allow first responders to better allocate the appropriate assets
in the event of a fire.
In 2024, Idaho Power collaborated with ALERTWest to install
five wildfire detection cameras in Idaho.The Bureau of Land
yManagement (BLM) Idaho brought a sixth site online in Idaho
Power's service area.Through coordination with the Idaho
Department of Lands, BLM Idaho, and Oregon Wildfire Detection
Camera Interoperability Committee, Idaho Power secured access to
an additional nine ALERTWest wildfire detection camera sites across
its Idaho and Oregon service areas.This network will provide critical
data on how wildfire detection technology can mitigate risks, reduce
wildfire impact, and enhance safety for Idaho Power's customers.
By working closely with federal, state, and local public safety
1 partners, Idaho Power achieved significant cost savings for its
' installed sites. In some cases, local partners provided tower space
at no cost, or installations were designed to eliminate the need for
towers. Idaho Power will continue to collaborate with these agencies
to identify future camera locations, focusing on opportunities that
deliver mutual benefits and cost efficiencies.
WM
ra

Table 2 provides a snapshot of Idaho Power's asset inspection and vegetation management activity in 2024
and goals for 2025. Idaho Power met or exceeded its 2024 goals as established in the WMP.
Table 2
Inspection and vegetation management program summary
Wildf ire Mitigation Plan Asset 2024 2024 2024 2025 2025
Inspection and Vegetation Goal Completed Completed Total% Goal Goal
Initiative Management Initiatives (OR and ID) (ID) (OR) Complete (ID) (OR)
Asset Transmission Inspections
Inspections Wildfire Pre-Season Patrol— 1,455 1,114 341 100% 1,114 341
Tier 3 Zones(Structures)
Ignition Prevention 341 n/a 341 100% n/a 341
Inspections
(OR Division 24)(structures)
Infrared Thermography Patrol 1,455 1,114 341 100% 1,114 341
(Structures)
Distribution Inspections
Wildfire Pre-Season Patrol— 21,162 19,382 1,780 100% 19,382 1,780
Tier 3 Zones(Poles)
Ignition Prevention 1,780 n/a 1,780 100% n/a 1,780
Inspections(OR Division 24)
(Poles)
Infrared Thermography 5,000 4,948 921 117% 4,000 1,000
Patrol—Tier 3
Zones(Poles)
Vegetation Pruning Cycle
Management Transition to a 3-Year 291 320** 9 110%** 150 37
Pruning Cycle(Circuits)
Enhanced Vegetation Management
Annual Patrol—Tier 2&3 149 139 13 102% 139 13
Zones(Circuits)
Annual Mitigation—Tier 2 149 139 13 100% 139 13
&3 Zones(Circuits)
Mid-Cycle Patrols—Tier 2&3 26 100% 7 —
Zones(Circuits)
Mid-Cycle Pruning—Tier 2 26 + + 100% 7 —
&3 Zones(Circuits)
Hazard Trees Identified 100%of All 32 — 100% 100%of All 100%of All
and Pruned Identified Identified Identified
Hazard Trees Identified 100%of All 50 — 100% 100%of All 100%of All
and Removed Identified Identified Identified
Audits of Pruning 100%of All 3,035 169 100% 100%of All 100%of All
Activities—Tier 2&3 Zones Identified Identified Identified
(Worksites)
"Value is a 2024-year end projection based on progress experienced through the first three quarters of the year.
•Accomplished with Annual Patrol in 2024(reported above)
+Accomplished with Annual Mitigation in 2024(reported above)

Vegetation Management
Idaho Power's Vegetation Management program (VMP) addresses public safety '
and electric reliability by safeguarding TO lines from trees and other vegetation
that may cause an outage or damage facilities.Vegetation management remains
an important mitigation strategy for Idaho Power.
Throughout 2024, Idaho Power continued to work toward a three-year pruning '!
cycle, although contract labor availability, contractor production, equipment
availability, and rising costs of these resources remain a challenge. Idaho Power
prioritizes tier 2 and 3 wildfire risk zones.The company conducts enhanced
vegetation activities, including annual patrols and mid-cycle pruning in those
higher risk areas.
s
o �
r

WMP Technology and Innovation
lessonsIdaho Power identifies and implements new wildfire mitigation technology based on continual evaluation
of industry learnings and practices, and technological advancements.The company approaches pilot
projects with the goal of learning about implementation complexities, efficacy for risk reduction,
and cost analysis of new technologies prior to full integration into the WMP.
Engagement in industry forums and workgroups like the International Wildfire Risk Mitigation Consortium
continue to provide a valuable venue for informal peer-to-peer sharing of emerging technology and
•• In 2024, •. • Power initiated or • •• its evaluationprocess of pilot projects
due in part to these interactions. Key learnings and results achieved during the pilot periods will determine
if the projects become part of Idaho Power's ongoing mitigation strategy.
Thermal Inspections: In certain locations, Idaho Power uses specialized thermal
imaging (infrared) equipment that can identify compromised electrical connections and
overloaded equipment that may not be apparent through other inspection processes.
Over the past two wildfire seasons, this work has detected several anomalies, including
t four issues in Tier 3 zones that were subsequently repaired. In 2025, Idaho Power plans
1V to continue thermal inspections in strategic locations.
Covered Conductor: As a field trial in 2024, Idaho Power installed
approximately one mile of covered conductor, including single-phase and three-phase
'dip + distribution, in a Tier 3 wildfire risk zone near Pocatello, Idaho.The objective of the trial
was to understand the feasibility of construction and maintenance, as well as prepare
{ construction standards, identify required material and equipment, and establish safe
and efficient work practices.Throughout 2025, the company will continue to analyze
the feasibility of integrating covered conductor more broadly.
f Cross-Boundary Fuels Reduction Collaboration: In 2024, Idaho
:`. Power participated in the Southern Idaho All Lands Partnership, an effort that
focuses on the planning and implementation of hazardous fuel reduction efforts
for wildfire-exposed communities in Idaho, including in Ada, Boise,Adams,Valley,
and Idaho counties.Through the partnership, Idaho Power worked closely with the
. f United States Forest Service; BLM; Idaho Department of Lands; National Forest
Foundation; and other federal, state, and local governments and fire agencies to
identify and prioritize projects that protect critical utility infrastructure.This partner-
driven work leverages and secures new funding sources to complete fuels reduction
projects.The partnership secured a five-year, $203M grant award in 2024 from the
Natural Resource Conservation Service to support forest and fuels treatments on
- private lands.
Pole Loading:As part of an ongoing pilot effort, Idaho Power is using
modeling software that creates 3-D representations of Idaho Power structures and
surroundings in Tier 3 wildfire risk zones to improve our understanding of potential
loading constraints on equipment that could lead to a failure.These assessments help
identify structural deficiencies based on pole class and the amount of equipment and
Joint Use attachments installed.The pilot project is anticipated to run through 2025.
Page 9

Operations
Field Personnel Practices
Idaho Power's wildfire mitigation strategy includes procedural
personnel measures to reduce potential ignition and the
spread of wildfires. Idaho Power developed a Wildland Fire
Preparedness and Prevention Plan (included as Appendix A
to this WMP) to provide guidance to Idaho Power employees
and contractors.The plan includes information on fire season
tools and equipment required on the job site; daily situational
awareness relative to areas where there is a heightened risk of
wildfire; expected actions and mechanisms for reducing on-the-
job wildfire risk, as well as reporting requirements in the event
of an ignition; and training and compliance requirements.
l Enhanced Protection Settings (EPS)
Sometimes called sensitive powerline settings, EPS are used to
reduce the probability of ignition during fault events on Idaho
Power's distribution system. Starting in 2024, the company
implemented a two-mode distribution protection strategy
during wildfire season:
EPS Mode 1: Auto-reclose turned off.This allows only
a single trip,which eliminates traditional re-energizations
to test the line, reducing chances of arcing or sparking.
EPS Mode 1 is generally operated as a seasonal setting and is
activated when fuel conditions reach a cured state, resulting
in increased fire potential. Mode 1 remains in effect until fuel
conditions change and there is decreased fire potential as
established by the company's Atmospheric Science team.
EPS Mode 2: Auto-recloser turned off and trip settings
set to instantaneous lockout.This is a much more sensitive
- r setting that will cause the AR device to lockout prior to most
fuses. Mode 2 is designed to minimize the fault energy,further
reducing the risk of arcing and sparking.
EPS Mode 2 is enabled in a wildfire risk zone based on
!E _
zone-specific wind and fire-weather criteria to reduce risk
¢ when fire-weather conditions are particularly elevated.
!� F Wildfire Monitoring
Throughout the summer months, Idaho Power monitors active
wildfires and tracks events as they progress.Wildfire tracking
informs operational planning and provides insight into areas
• �' or infrastructure that could be threatened throughout the fire
season. During active wildfire events, Idaho Power coordinates
~" with fire incident command to ensure safety of fire responders,
' protection of utility infrastructure, and timely
- - �� p Y ipower restoration
for customers in the event of an outage.
r
Page 10

Public Safety Power Shutoff (PSPS)
A PSPS, as used in this WMP, is defined as the proactive de-energization of electric transmission
or distribution lines during extreme weather events to reduce the risk of wildfire.
The decision regarding PSPS is based on several dynamic factors, and each weather event is unique.
While PSPS remains a last resort tool for Idaho Power, 78% of respondents to an Idaho Power customer
survey in October 2024 said they would support the use of PSPS in extreme weather conditions to
reduce wildfire risk. This approval rate is up seven percentage points from 71% the year before.
Idaho Power understands the complexity of PSPS, including potential impacts on vulnerable populations;
the ability for public safety partners to send and receive notifications across power-reliant platforms; and
fire suppression efforts that may be reliant on electricity to power wells and water pumps. Idaho Power
remains focused on limiting the impact and frequency of future PSPS events and continuously evaluates
initiatives under the WMP that could decrease the need for PSPS in the future.
1-2 Days Prior 1-4 Hours Prior Outage Begins Updates Power Restored
PSPS Watch PSPS Warning PSPS Outage Alert PSPS Updates PSPS Over
13
Sent when a PSPS Sent when a PSPS Sent when the PSPS Sent as needed and Sent when power has
event is likely. event is approaching. outage begins. when restoration been restored.
work begins.
Customer Communications
• Outreach
Safety is • of Idaho '• core values,
and it guides our strategy for wildfire-
•• communication to our customers
• the communities •. • Power
communicates with customers and the public
prior to and throughout wildfire season to
inform them of steps • •. •
i a
• reduce wildfire • ways they can help -
prevent wildfires and prepare for outages. --,j
Core approaches to communication include
social media, radio, customer
postcards, and voice and text messaging. In I N P E R S 0 N
2024, the company • • -• over :1 in-personand virtual meetings to engage with customers, MEETINGS
counties, fire protection agencies, and other
public organizations t• discuss and seek feedbackAND VIRTUAL
on the WIVIP and the company'splan.
Communication methods • metrics are
detailed in Section10 of the WMR

KEY TA K EAWAYS
and LESSONS LEARNED
� f rom
2 (oie=4
2024 Weather Review
Winter 2023-24 saw above-normal precipitation In September, precipitation was near normal
in the southern half of Idaho Power's service area region-wide.These conditions led to rapid drying
and below-normal in northern areas. Overall, wet- and curing of fine fuels across the lower elevations
season (October—May) precipitation was 70 to 90% by late June and increased fire danger in all areas
of normal in the Central Mountains and 110 to 150% from July through September. During this period of
of normal in southern Idaho and eastern Oregon.This elevated fire danger, several dry lightning events
precipitation distribution resulted in moderate drought occurred across the service area, with each event
conditions near Salmon and robust fine fuel growth bringing gusty winds and lightning ignitions.
across the southern half of the service area going into Idaho Power atmospheric scientists performed
late spring and early summer. frequent forecasts to determine a daily FPI value
Slightly below normal temperatures during May across the company's service area.The warm and
quickly transitioned to above normal in June and well dry conditions led to an increase in FPI levels
above normal in July,August, and September across throughout the summer of 2024, with distinct
the service area.The Pacific Northwest saw near- increases in mid-late July, mid-late August, early
record heat, with the Boise area seeing its second September, and early-mid October.The 2024 wildfire
hottest summer (June—August) on record since 18771. season saw 38 days in which a red FPI occurred in a
Precipitation from May through August was well below wildfire risk zone, compared to 12 days in 2023 and
normal across the service area, except for near-normal 33 days in 2022.
precipitation in southeast Idaho during August.
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NOAA National Weather Service.Boise Area Climate-Seasonal Totals.Updated online October 2024.Retrieved on October 21,2024,
from https://www.weather.gov/boi/seasonaltotals?station=BOIThr&season=summer&type=avgt
Page 12

1 V ®,
Omer..
2024 Wildfire Activity Key Learnings
The National Interagency Fire Center (NIFC) recorded The active wildfire season led to challenging, round-
252 wildfire starts and 1,509,455 acres burned in or the-clock emergency operations as Idaho Power
near Idaho Power's service area during the 2024 fire managed incoming weather systems and active
season.The number of fire starts was slightly above the wildfire encroachment on powerline infrastructure.
30-year average of 235.The number of acres burned While the number of wildfire starts across Idaho
almost doubled the 30-year average of 860,725 acres. Power's service area was not statistically significant
The season included several major wildfire events, compared to past years, the number of acres burned
with nine fires in or near Idaho Power's service area within five miles of Idaho Power's T&D system due to
exceeding 50,000 acres and four exceeding 100,000 wildfire was 260% of the 30-year average. In addition
acres.The largest wildfires occurred in eastern Oregon, to wildfire encroachment monitoring, the Idaho Power
western Idaho, and the Central Mountains, with most team was busy monitoring and assessing fire weather
started by lightning during late July, early August, and conditions to guide powerline operations.The 2024
early September. fire season saw 12 days with critical fire weather
NIFC has developed a National Preparedness Level (PL) conditions during which the company activated EPS
system ranging from 1 (lowest) to 5 (highest).The level Mode 2 on powerlines in wildfire risk zones.
reflects fuel and weather conditions, fire activity, and
resource availability across the country. During 2024,
NIFC reached PL 5 for a total of 59 days.This marked
the third-highest number of PL 5 days since records }�
began in 19902, highlighting the unusually active and I I.
persistent fire season.
,1
R
Aim
USDA Forest Service Northern Research Station-Understanding
the Wildland Urban Interface(1990-2020)(arcgis.com).
Page 13

PSPS — July 24, 2021
Throughout 2024, the PSPS assessment team assembled
three times to monitor potential extreme weather events. What is a
One event resulted in the company's first-ever PSPS PSPS?
event. In the days leading up to July 24, Idaho Power's � --� — --,, (--
Atmospheric Sciences team identified a large-scale weather
event that corresponded with very high temperatures, low ' PSPS is a last resort to reduce wildfire risk
humidity, and extremely high wind across eastern Oregon by cutting "power to an '
fire
and southwestern Idaho. risk is high due to extreme weather.
On Tuesday, July 23, the National Weather Service began issuing a series of weather warnings for
the following day, including excessive heat warnings, red flag warnings, and fire weather watches.
By Wednesday morning, the weather service issued Severe Thunderstorm warnings that included
the possibility of widespread wind gusts of 50 to 70 miles per hour (mph).
Idaho Power activated EPS Mode 2 in 53 wildfire risk zones and continuously tracked the incoming
event.At the same time, multiple wildfires were threatening Idaho Power infrastructure, including
the Durkee Fire in Oregon', which at the time was the largest fire in the country.
After seeing wind speeds and other data points that indicated a need for a PSPS, Idaho Power
de-energized lines in two wildfire risk zones in the greater Boise area around 5:40 p.m., affecting
approximately 8,845 customers.An additional 33,000 customers experienced unplanned outages
from the weather event.Approximately 18,000 of those customers were in areas where EPS Mode 2
was enabled. Once a weather all-clear was issued by Idaho Power's Atmospheric Sciences team,
safety patrols and storm damage repairs began. Service was restored for most customers affected
by the PSPS event by 3 a.m. the following morning.
The 2024 wildfire season and PSPS event highlighted key learnings
and opportunities for future improvement, including the need for:
An expanded network of fire-weather stations that have the capability of near real time data
return. Idaho Power's planned efforts for 2025 include the installation of 85 weather stations that
will refine forecasts and reduce reliance on field observers to monitor weather and wind conditions.
Continued installation of sectionalizing devices capable of remote operations.
The widespread nature of the July 24 weather event emphasized the importance of having
remote operation capabilities for devices protecting wildfire risk zones. Sectionalizing devices
also limit outage impacts on customers outside wildfire risk zones and speed up the
re-energization process during a PSPS event for those impacted by an outage.
Evaluating an event management platform capable of supporting high-volume, complex
customer communications.While Idaho Power was successful in communicating with customers
before, during, and after the PSPS event, the complexity of the simultaneous events led to the need
for detailed and customized messaging. Idaho Power is exploring new tools and capabilities for
coordinating, customizing, and tracking pre- and post-outage messages, including strategies to
improve the process for establishing an estimated time of restoration (ETR).
Wildfire Program Staffing and Capacity. Idaho Power has historically relied on existing staff to
come together for the planning and implementation of the WMP, including support of emergency
fire-season operations. In 2024, Idaho Power added dedicated positions to support the WMP with
plans to expand team capacity in 2025, including situational awareness, operations, technology
advancements, communications and outreach, project management, and regulatory engagement.
What to know:A map of Oregon's Durkee Fire,the largest in the U.S.
Page14

i �CYVf
� �^�C•1'.1 l
I.
1 i
N
i
2024 Messaging Approach and Community Feedback
Building from learnings in 2023, Idaho Power focused wildfire-related outreach primarily before
and during wildfire season. Focusing key communications during a time of year where wildfire
is more prominent on people's minds helped to increase the likelihood people would attend
meetings and other engagement opportunities. Early communications encourage customers to
think about wildfire season, how to prepare for it,their role in preventing wildfires, and steps
Idaho Power is taking to keep the grid safe and reduce wildfire risk.
As wildfire season neared, Idaho Power put more emphasis on asking customers to update their
contact information, prepare for wildfire or a potential PSPS event, and help prevent wildfires
while recreating. In November 2024, Idaho Power sent a customer survey to its Empowered
Community seeking feedback on attitudes about utilities and wildfire, including perceptions
of risk and support for mitigation measures.The company compared this survey to the
October 2023 survey, which the company used to establish a baseline for the effectiveness
of our wildfire communication.The following are high-level takeaways from the survey:
78 % 63 % 43 % 61 %
would support the use recalled hearing or recalled getting recalled receiving
of PSPS in extreme receiving information information about information about
weather conditions about PSPS from how Idaho Power how to prepare
to reduce the risk of Idaho Power or is working to reduce for outages
wildfire. through the media. wildfire risk.
(Up from 71% in 2023) (Up from 9% in 2023) (Up from 27% in 2023) (Up from 34% in 2023)
Page 15

Regulatory
As part of Idaho Power's commitment to deliver safe, reliable, and affordable energy, the company
developed the WMP to evaluate and reduce wildfire risk associated with its facilities.
The company's WMP is a living document that will continue to evolve. Idaho Power will continue to review,
modify, and expand the WMP to reflect shifts in industry best practices and to ensure the company is following
procedures and requirements established by its regulators.As a two-state utility, Idaho Power's regulators in
Idaho and Oregon provide meaningful input and recommendations on ways to improve the WMP.A recent
history of wildfire-related regulatory activities is provided below by state.
Idaho
Per Idaho Public Utilities Commission (IPUC) Order No. 35717, the company will submit each new WMP
to the IPUC and also provide pre- and post-wildfire season briefings.
Oregon
Oregon-specific wildfire requirements are memorialized in Oregon Administrative Rules, Division 300, which
specify elements of a utility's WMP.
Additionally, Idaho Power will continue to participate in shaping new WMP guidelines through the Public Utility
Commission of Oregon (OPUC) Docket No. UM 2340 and adhere to the new data submissions requirements as
specified in OPUC Order No. 24-326.
Idaho Power's Appendix D to the WMP provides Oregon-specific information related to wildfire requirements
and recommendations.
Page 16

Idaho Power Company Wildfire Mitigation Plan 2025
1. Introduction
1.1. Background
In recent years, the Western United States has experienced an increase in the frequency and
intensity of wildland fires (wildfires). A variety of factors have contributed in varying degrees to
this trend, including climate change, increased human encroachment in wildland areas,
historical land management practices, and changes in wildland and forest health. Although
Idaho has not experienced consequential fires to the same magnitude as some other western
states 4, Idaho's wildfire season has grown longer and more intense. Warmer temperatures,
reduced snowpack, and earlier snowmelt contribute to drier conditions, extending the period of
heightened fire risk. S
Idaho's wildfire season is defined by Idaho Code § 38-115 as extending from May 10 through
Oct. 20 each year, or as otherwise extended by the Director of the Idaho Department of Lands
(IDL). In 2024, the Director issued an extension of the fire season statewide 6 which remained in
effect until Nov. 1, 2024'. Oregon's wildfire season is designated by the State Forester each
year pursuant to Oregon Revised Statute § 477.505 and typically begins in June. Idaho Power's
operational practices account for the differences between Idaho and Oregon's wildfire seasons
and requirements.
1.2. Idaho Power Profile and Service Area
Idaho Power, headquartered in Boise, Idaho, is an investor-owned utility engaged in the
generation, transmission, and distribution of electricity. Idaho Power is regulated by the Federal
Energy Regulatory Commission (FERC) and the state regulatory commissions of Idaho and
Oregon. Idaho Power serves more than 640,000 customers with a culture of safety first,
integrity always, and respect for all.
Idaho Power's 24,000 square mile service area includes approximately 4,745 square miles in
Oregon and 19,255 in Idaho (Figure 2). The company serves approximately 20,000 customers in
Oregon and 620,000 in Idaho.
4 Wildland Fire Summaries 2019-2023.Statistics I National Interagency Fire Center(nifc.gov)October 8, 2024
6 Western Fire Chiefs Association.Idaho Fire Season:In-Depth Guide 1 WFCA Accessed October 8, 2024
6 Idaho Department of Lands Extends Closed Fire Season-Department of Lands
Idaho Department of Lands Rescinds Extended Closed Fire Season Order-Department of Lands
Page 17

Wildfire Mitigation Plan 2025 Idaho Power Company
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Idaho Power service area
Page 18

Idaho Power Company Wildfire Mitigation Plan 2025
1.3. Asset Overview
Idaho Power delivers electricity to its customers via 310 substations, approximately 4,727 miles of overhead transmission lines, and
approximately 19,446 miles of overhead distribution lines. Table 3 summarizes the overhead powerline asset information by state.
Additional detailed information on Idaho Power's assets is included in Section 8.
Table 3
Overhead transmission voltage level and approximate line mileage by state*
TOTAL IDAHO OREGON MONTANA NEVADA WYOMING
Asset Pole
Miles Pole Miles % Pole Miles % Pole Miles % Pole Miles % Pole Miles %
46 kV Transmission Lines 380 380 100.0% 0.0%
69 kV Transmission Lines 1077 683 63.0% 344 32.0% 50 5.0%
115 kV Transmission Lines 3 3 100.0%
138 kV Transmission Lines 1456 1249 85.0% 141 10.0% 66 5.0%
161 kV Transmission Lines 84 84 100.0% 0.0%
230 kV Transmission Lines 1149 930 81.0% 219 19.0%
345 kV Transmission Lines 475 365 77.0% 0.0% 110 23.0%
500 kV Transmission Lines 103 53 51.0% 50 49.0%
Total OH Transmission Lines 4727 3744 79.2% 757 16.0% 50 1.1% 66 1.4% 110 2.3%
Total OH Distribution Lines 19,446 17338 89.2% 2108 10.8%
Total OH Pole Miles 24,173 21,082 87.2% 2865 11.9% 50 0.2% 66 0.3% 110 0.5%
*Current as of as of Dec.31,2023.Line mileage reported includes co-owned assets.
Page 19

Wildfire Mitigation Plan 2025 Idaho Power Company
1.4. Objectives of this Wildfire Mitigation Plan
The primary objectives of this WMP are to identify and implement strategies to accomplish
the following:
1. 1. Reduce wildfire risk associated with Idaho Power's transmission and distribution
(T&D) facilities and associated field operations to protect public safety and reduce risk
to utility customers.
2. 2. Improve the resiliency of Idaho Power's T&D system in a wildfire event,
independent of the ignition source.
3. 3. Comply with all wildfire mitigation requirements established by its regulators.
Idaho Power's approach to achieving these objectives includes some of the following actions:
• Engage with government and industry entities, the public, and electric utility peers to
ensure understanding and commonality of wildfire mitigation plans.
• Utilize a risk-based approach to quantify wildland fire risk that considers wildfire
probability and consequence to identify areas of elevated wildfire risk within Idaho
Power's service area.
• Create specific and targeted operations and maintenance practices, system hardening
programs, vegetation management, and field personnel practices to mitigate
wildfire risk.
• Incorporate information regarding current and forecasted weather and field conditions
into operational practices to increase situational awareness.
• Employ public safety power shutoff(PSPS) protocols for Idaho Power's service area and
transmission corridors.
• Evaluate the performance and effectiveness of strategies identified in this WMP through
metrics and monitoring.
I.S. Wildfire Mitigation Plan Maturity
WMP "maturity" is an evolving topic of discussion across the utility industry and academia.
The purpose of so-called "maturity models" is to understand the evolution of a utility's WMP
based on established standard(s) of progress—most often specific to an individual state
regulator's objective. Maturity models and research-based studies on WMP maturity are in
various states of evolution.
In 2024, Stanford's Climate and Energy Policy Program published a white paper intended to
spotlight the evolution of utility WMP development, including identifying utilities leading the
way to reduce risk exposure. Idaho Power's WMP was classified under this study as Tier 1,
Page 20

Idaho Power Company Wildfire Mitigation Plan 2025
corresponding to the study's highest threshold in maturity analysis' relative to Federal
Emergency Management Agency (FEMA)-established wildfire risk ratings.
_ d
Wildfire Mitigation .I A ND
Plan Development
Tier 1 (High)
Tier 2(IntermedLate) OR SID
l L-
� Tier 3(Low)
NE
NV UT
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{ CA \1�.
NM Y0
1 b
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0 250 AAi 0 100 Mi 0 500 1.000 Mi
L�J LL i l 1 I
Figure 3
WMP development in western investor-owned electric utilities'
Annually, Idaho Power reviews its practices, outcomes, and benchmarks against the practices of
other utilities' WMPs. For the past two years, Idaho Power has referenced an established
maturity model to aid in its evaluation.
To date, two wildfire risk maturity models exist: the California Public Utilities Commission
Wildfire Safety Division (WSD) maturity model and the International Wildfire Risk Mitigation
Consortium (IWRMC) Wildfire Risk Mitigation Maturity Model. The WSD model was first
'Woods CEPP Wildire White Paper FINAL.pdf
9 Image derived from the Stanford Climate and Energy Policy Program whitepaper Wildfire:Assessing and Quantifying Risk Exposure and
Mitigation Across Western Utilities
Page 21

Wildfire Mitigation Plan 2025 Idaho Power Companx
deployed in 2020, and, in 2022, significantly expanded to beyond 1,000 survey questions that
encompass additional areas of focus, such as carbon reduction. The IWRMC Wildfire Risk
Mitigation Maturity Model was developed collaboratively among IWRMC member utilities as an
enhancement to the WSD maturity model and focuses on 50 key capabilities organized into 10
broad categories (see Figure 4, IWRMC Maturity Model Matrix). The IWRMC model has been,
and continues to be, tested among the Consortium's membership to validate findings and
identify opportunities for collective and individual utility improvement. As such, Idaho Power
considers the IWRMC Maturity Model to be a more appropriate assessment tool over the WSD
model for informing the company's approach for assessing programmatic maturity and
capabilities.
001iinternational Wildfire Risk Mitigation Consortium(IWRMC)
Wildfire Risk Mitigation Maturity Model
Overview of Key Capabilities
Maturity Category Key Capabilities
A. Risk L Estimation of ignition 2 Estmar-of wdnfuc 3.Lstimation of wlldfi re and C Climate/Weather S.Risk maps and
assessment and probability consequences pre-emptive power shutoff scenario modeling and simulation algorithms
mapping risk reduction Impact sensitivities
��y B. Situational 6.Weather variables 7.weather data resolution S.Weather forecasting 9.Weather vulnerability 10.Wildfire detection
',.'At�1f 1�7 awareness and utilized and damage prediction
forecasting
��,, 11.Prwritization and ILL Grid design for 13.Grid design for resiliency 14.Risk-based grid 1S.Evaluation and
,,41 "O C. Grid design and Justification of wildfire risk minimizing Ignition risk and minimizing pre-emptive hardening and cost Deployment of
11YlAl�I+ system mitigation grid design/ power shutoffs(ofefficiency Technology&Innovations
hardening system hardening applicable)
Initiatives
D.Asset 16.Asset inventory and 17.Asset inspection cycle 18.Asset inspections& 19.Asset maintenance 20.QA/QC for asset
management condition assessments diagnostic effectiveness and repair efficiency, management
and inspections effectiveness,and
compliance
21.Vegetation Inventory 22.Vegetation analytics& 23.Vegetation grow-in 24.Vegetation fall-In/ 2S.Fuel Load 26.QA/QC for
E. Vegetation
>I and condition assessment diagnostic effectiveness inspection and trimming/ hazard inspection and Management vegetation
management
and inspections data treatment process&cycle mitigation process& management
times cycle times
27.Protective equipment 28.Incorporating ignition 29.Pre-emptive power 30.Pre-emptive power 31.Pre-emptive power 32.Ignition
F. Grid operations and device settings risk factors in grid control shutoff operating model shutoff Initiation snutoff re-energization prevention and
and protocols and consequence mitigation protocols(If applicable) protocols fif applicable) suppression O n
(if applicable)
�a33.Data quality and 34.Data management 3S.Data democratization& 36.Data&ryber 37.Analytic solutions I G.Data comprehensiveness literary security
Iln governance
l r H. Resource 38.Benefit-cost 39.Portfolio wide initiative 40.Portfolio wide 41.Wildfire
©y allocation assessment and sceriano allocation methodology innovation in new wildfire Organization design,
methodology analysis initiatives resourcing,and skills
42.Wildfire plan 43.Plan to restore service 44.Emergency community 4S.Protocols in place to 46.Processes for
I. Emergency consistency with overall after wildfire related outage engagement during and learn from wildfire continuous improvement
planning and disaster/emergency plan after wildfire events after wildfire and pre
preparedness emptive power shutoffs
(if applicable)
47.Data and practices 48.Engagement with 49.Engagement and SO.Collaboration with
• J. Stakeholder
<-) sharing,and cooperation communities and communication with emergency response
cooperation and with external stakeholders stakeholders on wildfire disadvantaged populations agencies
community mitigation planning and
engagement
mitigation initiatives
Figure 4
IWRMC Maturity Model Matrix
In 2024, Idaho Power completed the IWRMC maturity model, and analyzed and benchmarked
data to inform maturation focus. Idaho Power identified four categories for maturation over
the next three years. Categories, capabilities, approach for maturation, and associated
implementation timelines are included in Table 4 below.
Page 22

Idaho Power Company Wildfire Mitigation Plan 2025
Table 4
Idaho Power IWRMC maturation approach
IMRMC Capability High-Level Approach Timeline
Category
Risk Mapping and Estimation of Ignition Probability(1) Incorporation of Technosylva 2024-2026
Simulation Wildfire Analyst software,
Estimation of wildfire and pre-emptive including Fire Risk and Fire Sim
power shutoff risk-reduction(3)
Grid Design and Prioritization and justification of wildfire risk Incorporation of Technosylva Fire 2024-2026
System Hardening mitigation grid design/system hardening(11) Sight Data Analysis and Weather
Research and Forecast model to
Risk based grid hardening and cost efficiency aid in programmatic decision
(14) making
Evaluation&deployment of technology and
innovations(15)
Grid Operations PSPS protocols,including for re-energization Cross-departmental Initiative to 2024-2025
and Protocols (31) review and assess all PSPS
protocols
Resource Wildfire organization design,resourcing,and Benchmarking of utility wildfire 2024-2025
Allocation and skills(41) organizational structures and skill
Methodology sets. Expand the Idaho Power
wildfire team as needed.
Page 23

Wildfire Mitigation Plan 2025 Idaho Power Company
2. Government, Industry, and Peer Utility Engagement
2.1. Objective
Idaho Power recognizes the importance of engaging with various levels of government—
federal, Idaho and Oregon State governments, and local governments—as an integral part of
mitigating wildfire risk. Idaho Power also recognizes the importance of engagement and
outreach with respect to potential future public safety power shutoff(PSPS) events to minimize
customer impact.
Idaho Power's WMP and outage preparedness strategy includes specific activities to engage
with key stakeholders to share information, gain feedback, and incorporate lessons learned.
Peer utility engagement ensures the company's efforts are informed by the best practices of its
peers in Idaho and Oregon.
2.2. Government Engagement
Much of Idaho Power's service area extends over forest and rangeland managed by the Bureau
of Land Management (BLM), U.S. Forest Service, and state agencies such as Idaho Department
of Lands and Oregon Department of Forestry. Prior to the start of fire season, Idaho Power
offers to meet with state and federal land-management agencies in Idaho and Oregon to review
the company's approach for wildfire mitigation and discuss wildfire season operations.
Throughout the year, Idaho Power continues to engage with state and federal agencies to share
information and to identify and work toward activities that are mutually beneficial.
For example, in 2024 Idaho Power participated in a wildfire roundtable hosted by Idaho
Governor Brad Little and Lt. Governor Scott Bedke. From this effort, the Governor's Office
produced a report outlining 10 Idaho-specific priorities to reduce the impacts of wildfire.10 The
report includes recommendations and directives intended for state agency directors on issues
such as liability reform for utilities and insurers, wildfire mitigation strategies, and statewide
communications. The report includes a directive for the Idaho Department of Lands,
Idaho Office of Energy and Mineral Resources, Office of Emergency Management, and Idaho
Transportation Department to lead an effort to establish a state-wide interoperability system
for coordinating wildland fire detection cameras. The directive is intended to engage federal
partners, including the BLM and U.S. Forest Service, to utilize lookout stations that could be
prime locations to install and monitor additional cameras. For the past two years, Idaho Power
has facilitated an effort with Idaho Department of Lands, the BLM, and the U.S. Forest Service
on the establishment of a wildfire detection camera network. These early coordination efforts
"Idaho Wildfire Report Recommendations August 2024
Page 24

Idaho Power Company Wildfire Mitigation Plan 2025
are laying the groundwork for what is intended to become a broader, state-facilitated
coordination effort moving forward.
Additionally, Idaho Power continues to be a member of the Southwest Idaho All-Lands
Partnership. The Partnership consists of representatives from federal and state agencies,
counties, fire protection districts, and non-profits. The group's mission is to reduce catastrophic
wildfire risk by pooling expertise and funding and creating a shared prioritization process for
targeting fuel reduction treatments across federal, state, and private forestlands in
southern Idaho.
Year-round, Idaho Power actively engages with both the Idaho Public Utilities Commission
(IPUC) and the Public Utility Commission of Oregon (OPUC) with respect to wildfire mitigation
activities. Idaho Power files its WMP annually with IPUC. In Oregon, the company is required to
submit an updated WMP by the end of each calendar year, which is then subject to a 180-day
review and approval process by the OPUC. Idaho Power continues to participate in the OPUC's
Oregon Wildfire and Electric Collaborative (OWEC) and ongoing rulemaking efforts.
2.3. Industry and Peer Utility Engagement
The first iterations of Idaho Power's WMP relied on learnings and processes developed by
several California utilities, with Idaho-specific modifications that account for the unique
qualities of Idaho Power's service area and risk profile. Idaho Power continues to engage with
utilities, including San Diego Gas and Electric (SDG&E), Southern California Edison, Pacific Gas
and Electric (PG&E), Sacramento Municipal Utility District, Liberty Electric, and PacifiCorp to
advance Idaho Power's WMP and stay up-to-date on evolving practices.
For example, in April of 2024, Idaho ^'
Power's wildfire team and members of —�.
executive leadership traveled to San
Diego to attend SDG&E's 2024 PSPS
tabletop exercise with public safety
partners. This provided an opportunity ��r
to observe SDG&E's approach to PSPS
training and engagement.
Learnings from this event were and = .�
continue to be incorporated into Idaho - -
.S
Power's PSPS program. In May of 2024, _
members of Idaho Power's Wildfire -
Mitigation team attended an inaugural
convening of PG&E's Near-Term,
Risk-Informed Wildfire Mitigation Figure 5
Discussion of Enhanced Protection Settings (EPS)with
Strategies for Utilities conference.
peer utilities at PG&E
More than 150 attendees from utilities
Page 25

Wildfire Mitigation Plan 2025 Idaho Power Company
across the U.S. came together in California for two days of panel-style discussions on topics
ranging from wildfire mitigation technology, customer engagement, PSPS protocols, and fire-
weather forecasting. During this conference, Idaho Power was introduced to Watch Duty, an
app-based platform that consolidates real-time, fire-weather information with wildfire
detection. Following the conference, Idaho Power integrated this technology into the
company's processes for detecting new wildfire starts.
Idaho Power also regularly collaborates with peer utilities from the Pacific Northwest and Rocky
Mountain Region, including but not limited to Avista Utilities, Portland General Electric (PGE),
Rocky Mountain Power, Pacific Power, Chelan County Public Utility District, Puget Sound
Energy, Excel Energy, NV Energy, Bonneville Power Administration (BPA), and Northwestern
Energy. Prior to the start of the 2024 Wildfire Season, Idaho Power hosted a Pacific Northwest
utility forum in Boise that centered on the sharing of WMP best practices, common challenges,
and innovative solutions for minimizing wildfire risk.
Additionally, Idaho Power is an active member of trade-based organizations that offer
wildfire-specific forums and discussions, including the International Wildfire Risk Mitigation
Consortium (IWRMC), Edison Electric Institute (EEI), and Western Energy Institute (WEI).
These forums are integral for sharing of information and best practices. For example,
the IWRMC was designed specifically as an industry-sponsored collaborative forum that
facilitates the sharing of wildfire risk mitigation insights and innovations from across the globe.
The program is led by a Utility Executive Steering Group, whose members work specifically on
wildfire/bushfire issues in Australia and the western U.S. Idaho Power's engagements with
IWRMC are focused on operations and protocols, asset management, vegetation management,
and risk management with additional participation from Idaho Power's vice president (VP) of
Planning, Engineering, and Construction in IWRMC's Executive Strategy Forums.
Throughout 2024, the wildfire mitigation team also participated in multiple workshops and
conferences with EEI and WEI that provided insights into emerging technologies and
advancements for WMPs. Additionally, Idaho Power's CEO and president is an active member
of the EEI Electricity Subsector Coordinating Council Wildfire Working Group. This working
group has been partnering with the U.S. Department of Energy (DOE) and other government
agencies to collectively minimize wildfire threats and potential impacts. In 2025, Idaho Power is
hosting WEI's annual Wildfire Mitigation Workshop in Boise.
Idaho Power views its ongoing collaboration with its peer utilities as critical for understanding
and ensuring commonality of wildfire mitigation plans, while accounting for the variation in
each utility's unique service area.
Page 26

2024 Industry, Fire Expert, and Peer Utility Engagement
Idaho Power continues to engage with academia, industry groups,wildfire experts and peers,
and peer utilities to gain knowledge of new mitigation activities, industry best practices, and
technology to reduce wildfire risk.The following provides an overview of Idaho Power's 2024
activities:
Academia
Boise State Hazard and Climate Resilience Institute (HCRI)—Participant in two HCRI-sponsored
networking events at Boise State University.
Stanford Climate and Energy Policy Program (CEPP) —Participated in CEPP's Wildfire Risk and
Mitigation Across Western Utilities Project and e-attended presentation for the CEPP on
assessing and quantifying risk exposure and mitigation across western utilities.
USDA Forest Service Northern Research Station (NRS),the Community Wildfire Planning
Center(CWPC), Portland State University(PSU)and the University of Colorado Denver—
Participated in the interviews for the "Fueling Adaptation" study,which is examining how
communities in areas of high wildfire risk are adapting to mitigate that risk, and how increased
federal investments made by the U.S. Department of Agriculture (USDA) Forest Service's
Wildfire Crisis Strategy may contribute to such efforts.
Industry Advancement and Technology
ANSI C119 Connector Committee 2024—Attended the C119.8 Meeting about Standards
Development on MV Piercing connector for Covered Conductor.
California Utility Forecaster Meeting(CUFM)—Held at San Diego Gas& Electric, a meeting of
western U.S. utilities and government weather and fire agencies to share strategies,
technologies, and lessons learned in forecasting fire weather and risk. Idaho Power gave a
presentation on our FPI forecasting process and met with other utility meteorologists about
how they forecast and communicate fire risk.
Clarion Webinar on Covered Conductor—Attended a virtual webinar on covered conductor
systems as a wildfire mitigation tool.
Distributech 2024—Attended conference and specific educational sessions on wildfire
mitigation including PG&E's Reliability Intervention Analytics and Portland General's journey to
an ADMS.
International Wildfire Risk Mitigation Consortium (IWRMC)—Idaho Power actively
participates in monthly workgroup forums for operations and protocols, asset management,
vegetation management, and risk management.
IEEE Expo, 2024—Attended the Institute of Electrical and Electronic Engineers (IEEE) Expo to
research material and technology related to wildfire mitigation strategies, including line
monitors, covered conductor stripping tools, covered conductor splicing covers
(heat shrink/cold shrink), and down conductor sensing technology.

2024 Industry, Fire Expert, and Peer Utility Engagement (Continued)
Madison Underground Distribution System Training(University of Wisconsin)2024—
Attended training that covered high-level cost comparisons for overhead to underground
line conversions, and applicable codes and standards that govern underground distribution
installations, cable, connector and equipment manufacturing considerations,
and overvoltage and current protections.
SKYDIO Ascend24 Conference—Idaho Power's UAS (drone)team lead participated in a panel
presentation highlighting how Idaho Power is using drones as part of the company's wildfire
mitigation plan.
Trees& Utilities Conference—Attended presentations specifically on technologies that could
be used to identify specific areas of potential Tree-to-Powerline contact.
Western Energy Institute (WEI)
• WEI Operations Conference, Oakland, CA—attended conference on distribution
operations including operations in wildfire risk areas.
• WEI Wildfire Planning and Mitigation, Oakland, CA—Attended a two-day conferen
focused on wildfire-specific mitigation activities and strategies.
• Overhead and Underground Electric Distribution Conference 2024—Attended the
Forum, Information, and Best Practices Sharing discussions on WMP, and Pole Fire
Mitigation Strategy presentation.
Western Undergrounding Committee—Attended forum and participated in information
sharing sessions on WMP approaches by Southern Cal Edison, Pacific Gas and Electric, Idah
Power, and San Diego Gas and Electric.
Technology—Idaho Power maintains and regularly updates our five-year WMP technology
roadmap.This roadmap provides a framework for ongoing evaluation of existing and new
technologies and informs the process for the incorporation of new innovations into our WMP
pilot project cycle.As part of our technology roadmap process, Idaho Power frequently
meets with a variety of wildfire technology vendors. Non-exhaustive examples are
included below:
Eaton: Ongoing work with Eaton to pilot the Form7 recloser control HiZ module.
ENSTO: Discussed covered conductor dead-end and piercing connectors.
Fire Dawg: Hosted an on-site demonstration of mobile community resource center
and additional services offered by the vendor.
Gridware: Met with Gridware to discuss their fault detection system that measures
a variety of mechanical forces on primary distribution lines, which can detect fault
conditions or other hazards.

2024 Industry, Fire Expert, and Peer Utility Engagement (Continued)
Kaddas: In a series of meetings throughout 2024 to discuss covered conductor.
Logic 20/20: Met with Logic 20/20 to discuss their risk modeling system and how it
could apply to our WMP.
Sentient Line Monitors: On-site meeting to discuss wildfire mitigation use cases
using MM3ai line sensors and ample analytics.
Siemens: Discussed Fuse Saver and other protection technology.
Watch Duty: Discussion of fire tracking, notification capabilities, and use cases
relative to the utility sector.
Peer-to-Peer Utility Engagements
Avista—Idaho Power's wildfire team met multiple times with the Avista wildfire team
throughout 2024 for focused discussions on PSPS operations and protocols.
CPUC 2024 Post-Season/Pre-Season Public Briefings on Utility Public Safety Power
Shutoffs—Attended a recap of PSPS activities in the California as presented by the
investor-owned utilities (IOU)to the PUC.
Northwestern—Idaho Power's wildfire team collaborated with Northwestern multiple tim
throughout 2024 including for wildfire detection cameras and PSPS protocols.
PacifiCorp
• One-on-one meeting to discuss PacifiCorp's EPS and technologies used for wildfire
risk mitigation.
• Idaho Power's wildfire team engages monthly with PacifiCorp's wildfire team to
discuss WMP approach and alignment across Idaho Power's Oregon and Idaho
service area.
Pacific NW Utility Wildfire Group—Idaho Power hosted a spring meeting in Boise with
attendance from utilities across the Pacific Northwest and Rocky Mountain regions.
Topics shared included details of Idaho Power's WMP and PSPS plan and collective discussion
on technology and innovative approaches to mitigation.
Portland General Electric—Idaho Power's wildfire team engages monthly with Portland
General's wildfire team to discuss WMP approaches and alignment across Idaho Power's
Oregon service area.
Pacific Gas and Electric(PG&E)
• Members of the PG&E team came to IPC headquarters in Boise to discuss wildfire
mitigation specific topics, including ignition tracking, enhanced vegetation management,
metrics, enhanced protection safety settings(EPSS) programs, and situational awarene
strategies.

2024 Industry, Fire Expert, and Peer Utility Engagement (Continued)
• PG&E+ Palantir:AIP Now for Public Safety Power Shutoffs. Online virtual meeting
hosted by PG&E to highlight work that Palantir has done for them, showing many of the
displays and actions that Palantir could employee for IPC if engaged.
• Maui Fire Meteorology—Idaho Power participated in a presentation on meteorologic
and fuel conditions leading up to and during the Maui Fire.
• PG&E and IPC Wildfire and Meteorology teams met to discuss weather research and
forecast modeling, including operations and incorporation of Technosylva in their
processes.
• One-on-one meeting to discuss PG&E's EPSS and technologies used for wildfire
risk mitigation.
Public Service of New Mexico—Meeting with leadership to discuss and provide details on
Idaho Power's WMP and learnings.
Rocky Mountain Power(RMP) —Idaho Power's leadership met with RMP to discuss
approaches managing wildfire encroachment.
San Diego Gas and Electric(SDG&E):
• 2024 Public Safety Power Shutoff Tabletop Exercise with Public Safety Partners
Idaho Power attended a hybrid event held at SDG&E that went through the PSPS
process discussing processes and actions during a PSPS as well as presentations
from vendors.
• SRP—One-on-one meeting with SDG&E's Electric System Protection engineers to
discuss sensitive relay profile (SRP) settings, and technologies used for wildfire
risk mitigation.
Xcel Energy Public Safety Power Shutoff Criteria Workshop—Participated in a PSPS Criteria
workshop that allowed participants (subject-matter experts [SME])to discuss threshold
criteria and refinement for PSPS decisions.The workshop was led by the Xcel wildfire
mitigation team designed to improve the resilience of Xcel Energy and booster their
PSPS program.
• 1

2024 Industry, Fire Expert, and Peer Utility Engagement (Continued)
Wildfire Mitigation Engagements and Learning
• Ada County Fire Adapted Communities(ADAFAC)Workgroup—Idaho Power is an active
partner of ADAFAC,which supports wildfire education and community preparedness.
• Bermuda Captive Insurance Companies— Presentations on Idaho Power's approach for
wildfire mitigation.
• Boise County Fire Chiefs—Presentation on Idaho Power's WMP and PSPS program.
• Bureau of Land Management—WMP discussion and pre-fire season preparedness
conversations with Oregon and Idaho BLM fire leadership.
• Environmental Idaho Series—Attended an in-person panel presentation on the 100-year
trend wildfire has taken in Idaho. Panelists included experts from the National Interagency
Fire Center(NIFC) and Idaho Climate Literacy Education Engagement and Research Group
(i-CLEER) at Boise State University.
• Firewise Events—Participated in two Firewise events in Boise including Firewise Day at the
Botanical Garden and the Exploring Wildly Series hosted by the City of Boise that included a
Firewise Garden tour and panel discussion.
• FEMA Incident Command System Training—IPC staff participated in both the ICS-100 and
ICS-200 online courses from FEMA and received certificates of completion.
• Idaho Power Energy Academy—WMP discussion with community leaders and businesses i
Ada County.
• Idaho Department of Health—Presentation on Idaho Power's WMP and PSPS program.
• Idaho Society of Healthcare Engineering—Presentation on Idaho Power's WMP and
PSPS program.
• 7th International Fire Behavior and Fuels Conference—Held in Boise, a forum where past
fire management experience and lessons learned are documented; current work showcased;
and emerging research, innovation, and techniques on fire management shared,towards
developing integrated solutions to these challenges. Idaho Power presented on
partnership-based fuels reduction efforts.
• LANDFIRE office hour sessions—Attended several webinar sessions focused on the
methodology used throughout the LANDFIRE 2023 update processing, including efforts to
improve vegetation classification accuracy and better understand the relationship between
fire simulation modeling and agricultural—urban interface environments.

Wildfire Mitigation1 •. • Power CO—n)r
2024 Industry, Fire Expert, and Peer Utility Engagement (Continued)
Page 32
• Moody's Insurance—Presentation on Idaho Power's approach for wildfire mitigation.
• National Interagency Fire Center(NIFC)—Continue to work with NIFC staff to learn more
about the Quantitative Wildfire Risk Assessment (QWRA) and Interagency Fuel Treatment
Decision Support System (IFTDSS) and assess the use of this tool in the in the utility setting.
• Oregon Wildfire Detection Camera Interoperability Committee—Evaluating the
siting/logistics,technology, governance, and financial needs associated with the growing
network of wildfire detection camera systems in Oregon.
• S&PClobal—Presentation on Idaho Power's approach for wildfire mitigation.
• U..S. Forest Service(USES) Leadership Engagement—Met with USES leadership,
including the Forest Service chief and regional forester for R4 to provide an overview of the
company's WMP and initiate conversation on collective opportunities for wildfire risk
mitigation work within and adjacent to Idaho Power's utility rights of way.

Idaho Power Company Wildfire Mitigation Plan 2025
3. Quantifying Wildland Fire Risk
3.1. Objective
Idaho Power's approach to quantifying wildland fire risk includes qualitative and quantitative
strategies to identify geographic areas of elevated wildfire risk if a wildfire ignites near a power
line. Mitigation actions and programs are prioritized in those areas identified as elevated
wildfire risk areas.
3.2. Identifying Areas of Elevated Wildfire Risk
Idaho Power works with an external consultant that specializes in assessing and quantifying the
threat of wildfire through a risk-based methodology that leverages weather modeling,
wildfire spread modeling, and Monte Carlo simulation. This methodology is commonly used
across the industry with other utilities in California, Oregon, Idaho, Nevada, and Utah utilizing a
similar approach to identify and quantify wildfire risk. The California Public Utilities Commission
(CPUC) utilized the same consultant as Idaho Power did in the original development of the
CPUC Fire Threat Map.
This wildfire risk-based methodology is consistent with conventional definitions of risk, which is
taken as an event's probability multiplied by its potential negative consequences or impacts
should that event occur. For Idaho Power's wildfire risk assessment, this formula is shown in
Figure 6.
Weather
LM
High
'irection
WM Businesses 0
Topography 7 Other Man-made Structures
Moderate
Fuel Types Present �� Acres Burned 0
Fuel Moisture Content Low
(dead or alive)
Figure 6
Wildfire risk-based methodology
Page 33

Wildfire Mitigation Plan 2025 Idaho Power Company
Each component is defined as follows:
• Fire Probability. Fire volume (i.e., spatial integral of fire area and flame length) is used
as Fire Probability because rapidly spreading fires are more likely to escape initial
containment efforts and become extended fires than slowly developing fires.
Data inputs used in the fire spread model to determine the fire volume (Fire Probability)
include historical weather, topography, fuel type, and fuel moisture content.
• Consequence. Estimation of the fire's impact on structures (i.e., homes, businesses,
other man-made structures) and acres burned.
• Wildfire Risk. Fire Probability multiplied by the Consequence. The highest Wildfire Risk
areas are those where both the Fire Probability and Consequence are elevated.
Conversely, combinations of low Fire Probability and elevated Consequence, or elevated
Fire Probability and low Consequence typically indicate lower Wildfire Risk.
3.2.1. Wildfire Risk Modeling Process
The wildfire risk modeling process incorporated the following major steps:
1. A 12-year (2011-2022) fire weather climatology was developed utilizing the Weather
Research and Forecasting (WRF) model to recreate historical days of fire weather
significance across Idaho Power's service area. This analysis generated
high-resolution hourly gridded fields of relative humidity, temperature, dead fuel
moisture, and wind speed/direction that was used as input to a Monte Carlo-based fire
modeling analysis.
2. Estimates of seasonal variation in live fuel moisture across Idaho Power's service area
were developed. This was accomplished by analyzing historical fuel measurements
and/or weather station observations. This step was necessary because live fuel moisture
data is needed for fire spread modeling, but the WRF weather model does not provide
live fuel moistures.
3. The federal LANDFIRE program was utilized to provide high-resolution
(approximately 100 feet) fuel rasters for use in fire spread modeling.11
4. The data developed above (WRF climatology, live fuel moisture, and LANDFIRE data)
was used to drive a Monte Carlo12 fire spread modeling analysis. This Monte Carlo
11 Lautenberger,C.W.,"Mapping areas at elevated risk of large-scale structure loss using Monte Carlo simulation and wildland fire modeling,"
Fire Safety Journal 91:768-775(2017).
z Ibid.
Page 34

Idaho Power Company Wildfire Mitigation Plan 2025
simulation was accomplished by randomly selecting an ignition location and a randomly
selected day from the fire weather climatology developed in step 1 above.
Ignition locations were limited in the model to be within a 240-meter buffer surrounding
Idaho Power's overhead transmission and distribution (T&D) lines (i.e., 120 meters on
either side). The model used equal ignition probability for all overhead distribution and
transmission asset types.13 Urbanized areas having underground circuitry were not
included in the model due to a low probability of wildfire associated with underground
electrical equipment. For each combination of ignition location and time of ignition,
fire progression was then modeled for 12 hours. For each modeled fire, potential fire
impacts to structures were quantified using structural location data. This was repeated
across Idaho Power's service area for millions of combinations of ignition location and
time of ignition.
5. The Monte Carlo results were processed, and GIS-based data depicting fine grained
wildfire risk was developed. This risk was then visually depicted on GIS-based wildfire
risk maps.
3.2.2. Establishing Wildfire Risk Zones
Based on the previously described modeling, draft risk tiers are generated algorithmically14
by an automated process. Tiers are established which, if exceeded, would classify an area as
Tier 2 (elevated risk) or Tier 3 (higher risk). This was accomplished by manually setting
threshold values at naturally occurring breaks and is a similar approach to that taken by the
CPUC in developing a state wildfire risk map. Consequently, the resulting risk tiers reflect risk
relative to Idaho Power's service area only and not absolute risk. Idaho Power color-codes the
tiers—yellow for Tier 2 and red for Tier 3 wildfire risk zones.
Iterative review of wildfire risk across the service area remains integral to the maturity of Idaho
Power's risk modeling methodology and is consistent with the ISO 31000 risk management
process that informs Idaho Power's WMP. Annual risk area adjustments are used to account for
unique factors that may increase or decrease risk due to changes that have occurred overtime,
such as increased development in a wildland urban interface or recent large-scale fires that
alter vegetation composition. In addition to the quantitative assessment provided by the
wildfire risk model, Idaho Power simultaneously utilizes a qualitative assessment process to
account for factors not incorporated into the wildfire risk modeling, detailed below in Figure 7.
is Transmission lines jointly owned by Idaho Power and PacifiCorp were included in the analysis.Furthermore,the proposed Boardman to
Hemingway(132H)500 kilovolt(kV)line route was also included in this analysis.
4 Ibid.
Page 35

Wildfire Mitigation Plan 2025 Idaho Power Company
F'Customelr
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Figure 7
Risk zone evaluation and determination process
Incorporating Local Feedback into Risk Zone Establishment
Throughout the year, Idaho Power routinely attends Local Emergency Planning Committees
(LEPC). Among other topics, this forum provides a platform to receive valuable feedback from
county-level public safety partners on the WMP, including risk areas, mitigation approaches,
outage preparedness, and emergency planning. Idaho Power also periodically meets one-on-
one with local fire departments and rural fire protection districts in Oregon and Idaho,
and state and federal resource managers, including Idaho Department of Lands,
Oregon Department of Forestry, Bureau of Land Management (BLM) district-level leadership in
Oregon and Idaho, and U.S. Forest Service (USFS) forest-level leadership in Idaho to review
Idaho Power's risk modeling process and gain feedback on localized areas relative to wildfire
risk. The feedback gained from these one-on-one meetings supports the understanding of
suppression capabilities, ingress/egress routes, and localized factors that may influence
fire regime.
Idaho Power's process for incorporating customer feedback into the WMP utilizes a variety of
approaches, including public workshops. Section 10 details Idaho Power's approach to
customer outreach and feedback relative to the WMP.
Page 36

Idaho Power Company Wildfire Mitigation Plan 2025
Wildfire Risk Zone Calibration with Peer Utilities
Idaho Power routinely engages with peer utilities and forums to benchmark and
continually evaluate the company's WMP activities and initiatives, including with the approach
to risk modeling. In 2024, Idaho Power participated in conversations with Rocky Mountain
Power, Portland General Electric, PacifiCorp, Bonneville Power Administration (BPA), and Avista
to better understand each utility's approach to risk assessment and risk zone designation.
Since joining the International Wildfire Risk Management Consortium (IWRMC) in 2023,
Idaho Power has also participated in a subgroup within the forum focused on risk-based topics,
including risk assessments, mapping, and modeling. Idaho Power defines consequence as a
fire's impact on structures and acres burned, thus the relative importance of these two factors
is primary to the company's determination of risk zones. Highly valued resources and assets
may be defined or weighted differently depending on the goals associated with wildfire
modeling and as such risk profiles can vary.15 Idaho Power will continue to work with peer
utilities to inform collective understanding and decision making around wildfire risk modeling
with the goal of continually improving Idaho Power's approach.
3.3. Wildfire Risk Zones
As detailed above, Idaho Power's wildfire risk zones reflect risk relative to Idaho Power's service
area only and not absolute risk. These zones guide our wildfire season operations and help
inform our approach to wildfire mitigation.
To aid in customer and public understanding, Idaho Power color-codes the tiers—yellow for
Tier 2 and red for Tier 3. The full risk zone map can be viewed in detail on Idaho Power's
website, and individual addresses can be entered on the map to determine proximity to
identified risk zones. For 2025, Idaho Power made four zone changes within the Idaho portion
of the service area (Table 5 and figures 8-9). Table 6 provides a breakdown of pole miles in risk
zones system-side and by state.
Table 5
2025 risk zone changes
State New Tier 2 New Tier 3
Idaho 4
Oregon -
Total 4
'5 Scott,Joe H.,et al.(2013).A wildfire risk assessment framework for land and resource management.United States Department of Agriculture,
Forest Service,Rocky Mountain Research Station.
Page 37

Wildfire Mitigation Plan 2025 Idaho Power Company
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Southern Region—2025 wildfire risk zone additions
Page 38

Idaho Power Company Wildfire Mitigation Plan 2025
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Western Region—2025 wildfire risk zone additions
Page 39

Wildfire Mitigation Plan 2025 Idaho Power Company
Table 6
Idaho Power's overhead transmission and distribution lines by risk zone in Idaho and Oregon*
All Idaho Lines in Wildfire Wildfire Risk Zones by State
Power Lines Risk Zones T2-Idaho T3-Idaho T2-Oregon T3-Oregon T2-Nevada T3-Nevada
Asset
Total Total ° Total ° Total ° Total ° Total ° Total
Pole /All Pole /All Pole /All Pole /All Pole /All Pole /°All Pole /°All
Total Pole
Miles LinesMiles Lines Miles Lines Miles Lines Miles Lines Miles Lines Miles Lines
Transmission
Lines 4604 421 9% 277 6% 115.85 2.5% 16.3 .4% 0 0.0% 11 0.2% 0 0%
Distribution
Lines 20995 1899 9% 984 4.7% 718 3.4% 40 0.2% 40 0.2% 0 0.0% 0 0%
Total Pole
Miles 25600 2320 9% 1262 4.9% 833 3.3% 56.3 0.2% 40 0.2% 11 0.0% 0 0%
*Total mileage current as of Dec.31,2023.Risk zone mileage current as of July 16,2024.Line mileage reported includes 100%Idaho Power-owned assets and does not include assets in co-ownership.
Page 40

Idaho Power Company Wildfire Mitigation Plan 2025
3.3.1. Maps
The following two-tier wildfire risk map in Figure 10, is illustrative of Tier 2 and Tier 3
throughout Idaho Power's service area. Additionally, figures 11 through 21 reflect Tier 3 zones
by region and service area. An illustrative map book of all zones is included in Appendix C. A full
and up-to-date risk zone map can be viewed in detail on Idaho Power's website.

Wildfire Mitigation Plan 2025 Idaho Power Company
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Page 42

Idaho Power Company Wildfire Mitigation Plan 2025
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Page 43

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Page 44

Idaho Power Company Wildfire Mitigation Plan 2025
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Page 45

Wildfire Mitigation Plan 2025 Idaho Power Company
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Page 46

Idaho Power Company Wildfire Mitigation Plan 2025
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Page 48

Idaho Power Company Wildfire Mitigation Plan 2025
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Page 50

Idaho Power Company Wildfire Mitigation Plan 2025
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Wildfire Mitigation Plan 2025 Idaho Power Company
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Page 52

Idaho Power Company Wildfire Mitigation Plan 2025
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Page 53

Wildfire Mitigation Plan 2025 Idaho Power Company
3.3.2. Boardman to Hemingway Proposed Transmission Line
Idaho Power specifically considered the proposed route of the 1321-1 500-kV transmission line as
part of the WMP. The proposed 1321-1 route was included in the wildfire risk assessment and
associated map analysis (see Figure 22). Two locations are identified along the route as having
elevated wildfire risk (Tier 2 zones), and there are no areas of higher risk (Tier 3 zones).
Although the 132H transmission line has not been constructed as of the publication of this 2025
WMP, Idaho Power intends this WMP (as it will be reviewed annually) will apply to 1321-1 once
constructed. Additionally, Idaho Power will continue to update its fire risk mapping periodically
and address the locations with elevated risk consistent with the mitigation strategy for
transmission lines as described in sections 5 through 9 of this WMP.
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Proposed 1321-1 route
Page 54

Idaho Power Company Wildfire Mitigation Plan 2025
4. Mitigation Approach
4.1. Objective
This section details Idaho Power's assessment of general risk with respect to undertaking
wildfire mitigation activities. This assessment provides a framework for understanding the
potential consequences of wildfire damage and the possibility of diminishing those
consequences through targeted mitigation activities.
To that end, Section 4.4 identifies selected mitigation activities and the estimated costs of those
activities on a system level. In Section 4.5, each mitigation activity is discussed in detail, with an
assessment of why it was selected, what alternatives (if any) may be available, and any
additional benefits (referred to as "co-benefits") the company believes may result from
pursuing it.
4.2. Risk-Based Cost and Benefit Analysis of Wildfire Mitigation
Idaho Power understands that wildfires have impacts beyond monetary costs, and it is
committed to taking the actions detailed in this WMP to reduce the risk of wildfire based on its
core values of safety, reliability, integrity, and affordability. That said, Idaho Power also
understands that its regulators and customers are interested in the monetary costs of wildfire
and wildfire mitigation. Idaho Power therefore provides a cost-benefit based analysis as part of
its WMP.
In assessing the probability and consequence of wildfire risk, and to identify benefits of various
wildfire mitigation efforts, Idaho Power engaged with an external consultant and considered
several sources of empirical data on the costs of major wildfires—both in terms of fires that
burn into Idaho Power's facilities or that originate from electric infrastructure. These costs can
include replacement costs of the company's property; the cost of fire suppression and
environmental damage; third-party claims for property damage; employee and public injuries
and fatalities; and other economic losses.
Through its research, Idaho Power found that obtaining a precise calculation of the potential
costs of future wildfires is not possible. The damage that any fire may cause depends on factors
such as wind and weather, vegetation, fire risk levels, location, and population and
structure density.
Idaho Power's assessment of the potential costs of wildfires—used in developing the WMP and
the scope of proposed updates to practices—involved a review of prior major fires in other
states, as well as calculations by other western utilities. While this assessment did not yield a
precise quantification of potential benefits specific to Idaho Power, it provides a helpful
illustration of the potential costs of not taking actions aimed at reducing wildfire risk.
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Wildfire Mitigation Plan 2025 Idaho Power Company
For example the Maui wildfires in 2023 are expected to exceed $12 billion16 and in California,
costs and damages associated with wildfires in recent years have exceeded $10 billion per year,
with those associated with the 2020 fires alone potentially set to exceed $20 billion.17
This increase18 is consistent with the fact that, with few exceptions, the prevalence, intensity,
and impact of wildfires continues to escalate year after year as evidenced by information
compiled by the California Department of Forestry and Fire Protection (CAL FIRE) and detailed
in Table 7.
Table 7
CAL FIRE wildfire data by year
Estimated Acres No.of Confirmed No.of Structures
Year Burned No.of Wildfires Fatalities Damaged or
Destroyed
2024* 1,040,146 7,668 1 2,077
2023 332,822 7,386 4 157
2022 331,358 7,477 9 946
2021 2,569,386 7,396 3 3,560
2020 4,197,628 9,279 31 11,116
2019 259,823 7,860 3 703
2018 1,975,086 7,948 100 22,868
2017 1,548,429 9,270 47 10,868
2016 669,534 6,954 6 1,274
*As of November 15,2024
The data compiled by peer utilities, historic fire costs, and known damage from prior fires are
instructive and reasonably conclude that the incremental costs of wildfire mitigation efforts are
prudent. Considering the available historical information and data regarding wildfire risks and
losses, Idaho Power is working with PacifiCorp and Portland General Electric as a joint utility
working group on a strategy for the future creation of a common framework evaluating risk
reduction benefits relative to cost.
Risk spend efficiency (RSE) is a tool that can be used to better understand how a proposed
mitigation approach may incrementally reduce wildfire risk. At a basic level, RSE is calculated as
e Kevin Knodell,Overall costs for the Maui wildfires are expected to top$12 billion,The Star Advertiser,November 21,2024,at
https://www.staradvertiser.com/2024/08/10/hawaii-news/overall-costs-for-maui-wildfires-are-expected-to-top-12-billion.
Jill Cowan,How Much Will the Wildfires Cost?,The New York Times,Sept.16,2020,at nytimes.com/2020/09/16/us/california-fires-cost.html.
8 Idaho Power believes its system is in notably better condition than some utilities in California.Nevertheless,these figures illustrate the
destruction that can occur from vegetation contact if vegetation is not actively managed.
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Idaho Power Company Wildfire Mitigation Plan 2025
a ratio between overall cost and risk reduction achieved. RSE includes analyzing risk mitigation
alternatives, the expected risk reduction, and considers the lifecycle costs and other constraints
of the mitigation. RSE metrics can be compared to one another, ultimately allowing for the
ability to assess one mitigation approach against another to evaluate the effectiveness of an
investment relative to reducing wildfire risk while minimizing ratepayer impact.
With RSE being a ratio, it is important to note that mitigations with high costs and high
associated risk reduction may have the same RSE as mitigation with low cost and small
associated risk reduction. RSE is not a measure that can indicate if a risk reduction threshold is
being achieved and, accordingly, desired risk levels may warrant greater spend to achieve the
objectives of an independent utility's WMP. Idaho Power will continue to expand RSE efforts
with a specific focus on trying to accurately quantify risk reduction and to determine how RSE
may be used as one of many inputs in the overall decision-making processes for mitigation
approaches and alternatives.
4.3. Risk Analysis and Drivers
Idaho Power's risk management framework is modeled after the internationally recognized risk
management standard, ISO 31000. ISO 31000 provides a comprehensive framework for
effective risk management with six distinct steps summarized in the graphic below.
improvementr-Mon-itor, review, Risk Identification
L continuous
WMP
Objectives
DevelopmentRisk Mitigation
Figure 23
Idaho Power WMP risk management framework
The framework provides Idaho Power with a structured approach to wildfire mitigation
planning by enabling systematic identification, assessment, and management of wildfire risk.
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Wildfire Mitigation Plan 2025 Idaho Power Company
Idaho Power faces evolving wildfire risk and continues to advance its risk management
processes to better understand sources of risk and to identify the best solutions to further
reduce risk in the future. Managing risk is an evolving process and while not all risk can be
eliminated, Idaho Power's goal is to proactively prepare and enhance its infrastructure and
operational practices to deliver safe and reliable energy today and in the future. The company
continues to work to systematically identify, analyze, evaluate, mitigate, and monitor risks
associated with wildfire.
In 2023, Idaho Power partnered with a consulting firm to reassess ignition risks from overhead
transmission and distribution facilities and gain a deeper understanding of how wildfire risk can
be quantified. A project team was formed and held three workshops throughout the year with
subject-matter experts (SME) from various departments within the company. The team used
the ISO 31000 standard as a guide for identifying and evaluating equipment-specific risks in the
context of wildfire ignition. Risk drivers and scenarios were analyzed to determine the
likelihood and impact of wildfire, which led to the creation of the risk bow-tie diagram,
shown in Figure 24, and used as a visual representation of risk. The company plans to
re-evaluate risk drivers in 2025 and incorporate information from ignition tracking efforts into
the review process, providing insights from past incidents and near-miss events.
r- Risk Drivers Triggering Event Risk Impacts
wa-YWn object Safety
Vegetation
Animals
Vehicle collisi
Damage
M
Insulator
Transformer Ignition
Wildfire
onductor/Splice/Conrector Financial Loss
files
High winds and low humidity Outage
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ndalism
nstruction activities/Work Environmental
Figure 24
Risk bow-tie diagram
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Idaho Power Company Wildfire Mitigation Plan 2025
The bow-tie analysis considers the risk exposure throughout Idaho Power's 24,000 square mile
service area and locations having overhead transmission and distribution facilities. The bow-tie
is constructed using three components described below.
• The Triggering Event: The event Idaho Power aims to avoid that could
impact the company's ability to meet its objectives of providing safe, reliable,
and affordable energy.
• Risk Drivers: Factors that may potentially lead to an ignition are listed on the left side of
the bow tie. Actual conditions play a key role in whether a wildfire occurs as a result of
an ignition, and it is important to note the risk drivers shown are only an indication that
a risk event may occur.
• Contact from a foreign object—Contact with foreign objects, including vegetation,
animals, balloons, and other wind-blown objects.
• Equipment failure—The unexpected failure of line equipment due to discrete
(internal) or destructive (external) conditional changes.
• Environmental—Extreme weather conditions that include high wind, low humidity,
and drought contribute to increase the risk of wildfire and can lead to tree failure,
vegetation contact, and failure of electrical equipment.
• Other—Overhead powerlines may be at risk of vehicle collisions, vandalism,
or physical attack. Construction activities, including activities performed by
sub-contractors, near overhead powerlines may be a risk driver if proper safety
precautions are not taken to eliminate inadvertent equipment contact.
• Risk Impacts: While most fires are extinguished quickly, the right side of the bow-tie
describes the range of possible outcomes associated with the risk event. Impacts vary
largely based on where the event occurs and actual conditions. The impacts shown are
worst-case scenarios.
Idaho Power has identified and implemented mitigations for each of the top risk drivers shown
in the risk bow-tie with details provided throughout the WMP. Each type of mitigation is
designed to reduce one or more of the risk driver frequencies or modify the potential impacts
or outcomes. Primary mitigation programs and activities include overhead circuit hardening,
underground conversions, expanded vegetation management and asset inspections, and public
safety power shutoff(PSPS).
4.3.1. Probabilistic Risk Modeling
Idaho Power's approach to performing wildfire risk assessments includes the identification of
hazards and estimating their relative likelihood of occurrence and potential consequences
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Wildfire Mitigation Plan 2025 Idaho Power Company
through feedback from SMEs and utilizing data when available. In 2024, the company began to
integrate data science into wildfire risk assessments by combining analytics with new and
existing data sources to provide greater insight into predicting asset failure and vegetation risk.
This work will enable the company to leverage large volumes of data for predictive insights and
help inform decision-making. The company expects that implementing a data-driven approach
will take several years to mature and will provide insights to help prioritize infrastructure
upgrades and identify which risk-management strategies are most appropriate given practical
constraints, such as limited resources and time.
As part of this effort, in 2024, Idaho Power began work to enhance existing risk quantification
methods by integrating asset parameters, such as age, conductor type, phasing, and outage
history into the company's existing risk data. The team will continue this work in parallel with
the implementation of new wildfire risk modeling software,Technosylva, to ultimately lead to a
detailed distribution circuit-specific ranking (or circuit segment ranking). The enhanced risk
scores will also establish a baseline that will enable calculation of the risk reduction benefit
(RSE) from specific mitigation practices.
In 2024, the company began work combining analytics with vegetation management activities
by developing a probabilistic model called Vegetation Risk Index (VRI). The VRI is intended to
help Idaho Power quantify the likelihood of vegetation contact under specific conditions, such
as extreme weather events. The model considers variables such as tree density, species, outage
history, and meteorology data, which helps provide insight into how atmospheric conditions
may impact growth rates of certain species and where certain high-risk vegetation areas may
exist as conditions change. The model is anticipated to provide a co-benefit of informing where
Idaho Power may want to focus additional tree inspection activities in advance of wildfire
season or on certain high-risk days that include PSPS events. Work performed thus far has
demonstrated the potential benefits of combining innovative analytics with traditional
mitigation practices to enhance reliability, reduce risks, and ensure public safety. Idaho Power
anticipates completing an initial version of the VRI in 2025 and will begin utilizing it once it is
finalized. .
4.4. Wildfire Mitigation Cost Summary
From 2025 through 2029, Idaho Power estimates investing $275 million in operations and
maintenance (O&M) expenses to further wildfire mitigation measures. Table 8 summarizes
the company's planned expenditures associated with executing its WMP through 2029.
Estimated amounts reflect the company's best estimates and plans as of the 2024 WMP.
These estimates will likely change in the future as the company reviews and refines its WMP
and associated mitigation activities. For the 2025 WMP, each wildfire mitigation category—
and associated estimated expenditures in Oregon and Idaho—is discussed in Section 4.5.
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Idaho Power Company Wildfire Mitigation Plan 2025
Table 8
Estimated system-wide O&M expenses for wildfire mitigation, $000s (2024-2029)*
*As of December 29,2024.
5-Year
5-Year 5-Year
2025 2026 2027 2028 2029 Forecast Forecast
Forecast Forecast Forecast Forecast Forecast Forecast Total Total
Total Idaho Oregon
A.Quantifying Wildland Fire Risk
Dynamic Risk Modeling-Risk Maps,Fire Simulation,Risk
Spend Efficiency,Probabilistic Model Development and $2,040 $2,385 $2,385 $2,502 $2,502 $11,814 $11,223 $591
Support
B.Situational Awareness
Weather Forecasting-System development and $302 $33 $8 $8 $8 $359 $341 $18
support,data services,climatology
Weather Forecasting Personnel-Fire Potential Index $171 $176 $181 $187 $192 $908 $862 $45
(FPI)and Public Safety Power Shutoff(PSPS)
Weather Forecasting-Weather Station Maintenance $41 $212 $306 $327 $348 $1,234 $1,172 $62
Pole Loading Modeling&Assessment(Contract service) $75 $75 $75 $75 $75 $375 $356 $19
Wildfire Detection Cameras $190 $255 $315 $375 $435 $1,570 $1,492 $79
C.Mitigation-Field Personnel Practices
Tools/Equipment $5 $5 $5 $5 $5 $25 $24 $1
Mobile Weather Kits for Field Observers $2 $2 $2 $2 $2 $10 $10 $1
International Wildfire Risk Mitigation Consortium $40 $40 $42 $42 $42 $206 $196 $10
D.Mitigation-Transmission&Distribution Programs
O&M Component of Capital Work $130 $156 $183 $201 $210 $879 $835 $44
Annual O&M T&D Patrol Maintenance Repairs $100 $300 $300 $300 $300 $1,300 $1,235 $65
Environmental Management Practices $25 $25 $25 $25 $25 $125 $- $125
Transmission Thermography Inspection Mitigation $50 $50 $50 $50 $50 $250 $85 $165
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Wildfire Mitigation Plan 2025 Idaho Power Company
5-Year
5-Year 5-Year
2025 2026 2027 2028 2029 Forecast Forecast
Forecast Forecast Forecast Forecast Forecast Forecast Total Total
Total Idaho Oregon
Distribution Thermography Inspection Mitigation $30 $30 $30 $30 $30 $150 $143 $8
Thermography Technician Personnel $159 $164 $169 $174 $179 $844 $802 $42
Transmission Wood Pole Fire Resistant Wraps $250 $250 $250 $250 $250 $1,250 $1,188 $63
Wildfire Mitigation Program Labor $1,338 $1,378 $1,419 $1,462 $1,506 $7,104 $6,748 $355
Patrolmen for Wildfire Safety Inspections in Wildfire Risk $253 $358 $369 $380 $391 $1,751 $1,663 $88
Zones
Covered Wire Evaluation-Pilot Program in PSPS Zones $20 $- $- $- $- $20 $19 $1
Drone Beyond Visual Line of Sight Waiver for PSPS $120 $120 $- $- $- $240 $228 $12
Patrols
Aerial Drone Inspection Pilot $214 $380 $390 $399 $409 $1,792 $1,702 $90
E.Vegetation Management
Transition to/Maintain 3-year Vegetation Management $42,200 $45,576 $43,297 $45,462 $49,099 $225,634 $210,946 $14,688
Cycle
Enhanced Practices for Distribution Red&Yellow Risk
Zones(Pre-Fire Season Patrols/Mitigation,Pole Clearing, $1,486 $1,709 $1,760 $1,813 $1,839 $8,607 $7,689 $918
Removals,Work QA)
Line Clearing Personnel $173 $178 $184 $189 $195 $919 $873 $46
Fuel Reduction Program $75 $75 $75 75 75 $375 $356 $19
Vegetation Mgmt.Satel lite/Aerial/Li DAR $100 $100 $100 $100 $100 $500 $475 $25
F.Communications
Wildfire/Wildfire Mitigation Education/Communication-
Advertisements,Bill Inserts,Meetings,Other&PSPS $171 $171 $171
Customer Education/Communication-Advertisements, $171 $171 $855 $812 $43
Bill Inserts,Other
Public meetings/event fees for PSPS engagement,maps, $10 $10 $10 $10 $10 $50 $40 $10
flyers
PSPS and Wildfire Event Management Support $188 $194 $200 $206 $212 $1,001 $951 $50
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Idaho Power Company Wildfire Mitigation Plan 2025
5-Year
5-Year 5-Year
2025 2026 2027 2028 2029 Forecast Forecast
Forecast Forecast Forecast Forecast Forecast Forecast Total Total
Total Idaho Oregon
Community and Customer Engagement and Outreach $161 $166 $171 $176 $181 $187 $177 $9
G.PSPS/Emergency Preparedness and Technology
Communication/Alert Tool development(System set up,
outage maps,critical facilities identification) $ 5 5 5 5 $20 $19 $1
Communication/Alert Tool for PSPS Customer 200 200 200 200 200 $1,000 $950 $50
Alerts/Extended Use
PSPS and Wildfire Encroachment Event Management $- 50 53 55 58 $216 $205 $11
Softwa re
Fire Suppression Resources 105 110 116 121 127 $579 $550 $29
Standby Helicopter Service 560 577 594 612 630 $2,973 $2,824 $149
Community Resource Centers 5 5 5 5 5 $25 $24 $1
Mobile Generators 30 30 30 30 30 $150 $143 $8
Total $51,019 $55,550 $53,474 $56,023 $59,897 $275,295 $257,358 $17,937
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Wildfire Mitigation Plan 2025 Idaho Power Company
4.5. Wildfire Mitigation Activities
Idaho Power utilizes individual wildfire risk mitigation activities based on a variety of factors,
including assessment of industry best practices in wildfire mitigation; discussions with peer
utilities; consultation with government entities and agencies; and with consideration of
alternatives that could be pursued. While these initiatives are primarily intended to mitigate
the risk and impacts associated with wildfire, additional co-benefits such as increased safety,
reliability, and resiliency of the system are also achieved (see Table 9). As such, Idaho Power
considers co-benefits a part of the evaluation process. Below is a narrative of each mitigation
activity, its purpose, estimated near-term cost, additional potential co-benefits of the activity to
Idaho Power and its customers, and possible alternatives.
With respect to Idaho and Oregon cost estimates, the estimated costs identified below are
grounded in cost assignment between the company's Idaho and Oregon service areas and
further informed by anticipated work in the two service areas.
Table 9
Safety, reliability, and resilience co-benefits of wildfire mitigation initiatives
Mitigation Initiative Safety Reliability Resiliency
Defined as the potential Defined as the ability of Defined as the
to pose a danger,risk,or the power system to ability for the grid
injury to life or property withstand instability, system to adopt to,
uncontrolled events, withstand,and
cascading failures,or quickly recover from
unanticipated loss of disruptive events or
system components changes within the
surrounding
environment
Enhanced Vegetation Management X X
Asset Inspections and Corrections X X
Grid Hardening X X X
Undergrounding X X X
Quantifying Wildfire Risk X
Situational Awareness—Weather Forecasting, X X X
FPI,Weather Stations
R&D X X
Advanced Technologies—Wildfire Detection X X
Cameras
Advanced Technologies—Pole Loading X X
Covered Conductor Pilot X X X
Community Programs X
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Idaho Power Company Wildfire Mitigation Plan 2025
4.5.1. Quantifying Wildland Fire Risk
Idaho Power's process for establishing wildfire risk zones is discussed in Section 3 of this WMP.
The first step in developing Idaho Power's WMP was to conduct a comprehensive assessment
of the company's service area and transmission corridors. The company worked with a
consulting firm that specializes in wildfire risk modeling and fire science to conduct Idaho
Power's wildfire risk analysis. The company determined that hiring an external consultant was
beneficial for two reasons: 1) an external consultant was more cost effective than hiring
additional resources within Idaho Power to perform the modeling, and 2) an outside consultant
helped ensure Idaho Power's risk analysis approach aligned with other utilities' practices thus
creating a basis for comparison of risk including standard terminology and methodology.
Idaho Power deemed Reax Engineering a qualified consultant to perform wildfire risk analysis
based on the work it performed for the California Public Utilities Commission (CPUC) in
developing the CPUC Fire Threat Map. Other utilities in Oregon, Idaho, Nevada, and Utah have
utilized similar modeling approaches to identify and quantify wildfire risk.
In 2024, Idaho Power began the process of integrating Technosylva Wildfire Analyst Enterprise
(WFA-E) software into the company's approach for wildfire risk identification and
quantification. WFA-E integration is anticipated to continue throughout the first two quarters of
calendar year 2025, with operational capability targeted prior to the start of the 2025 wildfire
season.
WFA-E is a cloud-based SaaS platform that provides on-demand wildfire spread prediction
capabilities to support operational response, what-if scenario analysis, and wildfire risk
forecasting. WFA-E is comprised of a Daily Operational Risk Package, which includes Fire Risk
and FireSim Software and Forecast Data, and a Mitigation Planning Package which includes
FireSight Analysis and Software.
• FireSim provides an on-demand capability within WFA-E to create spread predictions
and obtain detailed information on potential impacts within seconds of an incident
notification. Impact analysis, including at-risk populations, structures and buildings,
critical facilities, and company assets, is automatically undertaken with each
prediction—all within less than a minute. This information is critical for infrastructure
protection, response, and resource prioritization.
• FireRisk integrates advanced weather forecasts with FireSim modeling to perform
hundreds of millions of fire simulations daily to derive both current and near-term risk
forecasts for customer service territories and critical assets. New forecasts are derived
daily intended to provide accurate and timely analysis of possible wildfire events.
Baseline risk and consequence metrics are derived by identifying at-risk populations,
buildings, and critical facilities that may be impacted. Risk metrics are calculated hourly
for infrastructure assets to support possible PSPS de-energization analysis, as well as
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Wildfire Mitigation Plan 2025 Idaho Power Company
emergency operations center activation, stakeholder and public notification, and
resource allocation and deployment.
• FireSight generates millions of simulations to estimate potential wildfire spread
scenarios under varying fire weather conditions across the 600 most significant wildfire
days within a 20-year historical weather database. These simulations can then be used
to estimate the potential consequences of failure and ignition at the feeder and
sub-feeder level, helping to determine the risk associated with assets, and improving
the understanding associated with asset hardening decisions that can be prioritized
through an RSE analysis and other developed metrics.
The company is also developing a probabilistic model to enhance its wildfire mitigation
strategies. With the help of a contractor that specializes in data science and machine learning,
Idaho Power plans to incorporate analytics with new and existing data sources to provide
greater insight into predicting vegetation hazards. See Section 4.3.1 for more information.
Ongoing costs include development and support from the contractor and access to available
data sources. Hiring a contractor to develop the model offers several advantages over
attempting to create the models in-house. The advantages include specialized expertise, cost-
efficiency, time savings, and ability to leverage experience in a tailored approach for wildfire
risk analysis. The company expects the development of the model will provide a co-benefit of
being able to apply the principles learned to other areas of risk mitigation.
5-Year Cost Estimate for Quantifying Wildland Fire Risk(2025-2029)
0 Starting in 2025, Idaho Power will utilize the Technosylva WFA-E software to support re-evaluation
of wildland fire risk across the Idaho Power service area.The company will also utilize a consultant
to develop a VRI for assessing vegetation risk on a real-time basis. Idaho Power estimates system-
wide expenditure for these services to be approximately$11.8 million between 2025 and 2029.
4.5.2. Situational Awareness—Weather Forecasting Activities and Personnel
Idaho Power discusses specific situational awareness practices in Section 5 of this WMP.
In 2020, Idaho Power created an FPI tool to support operational decision-making to reduce
wildfire threats and risks. The tool takes data on weather, prevalence of fuel (i.e., trees, shrubs,
grasses), and topography, and converts that data into an easily understood forecast of the
short-term fire threat for different geographic regions in Idaho Power's service area. Since the
original development of the FPI, Idaho Power has continued to enhance its meteorological and
weather forecasting capabilities to enhance FPI accuracy.
The benefit of developing the FPI and enhancing the company's meteorological forecasting
capabilities includes greater situational awareness of Idaho Power's system during critical peak
summer months. To continue to generate useful information and system benefits,
Idaho Power's situational awareness activities are evaluated and updated annually as necessary
to support the company's wildfire preparedness.
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Idaho Power Company Wildfire Mitigation Plan 2025
The company considers the FPI and related efforts, such as the deployment of fire-weather
stations, an essential part of reducing the risk of ignition from work activities. This provides
Idaho Power field personnel a tool to assess the fire potential on a consistent basis and across
the service area. Given the distinct benefits that result from the FPI and enhanced forecasting
capabilities, Idaho Power did not consider alternatives to the development of these
critical tools.
In conjunction with the FPI, the incorporation of Technosylva WFA-E will improve situational
awareness capability by informing real-time wildfire forecasting and Idaho Power's wildfire
simulation capabilities. In 2025, the company will focus on enhancing its weather forecasting
capabilities in the context of decision-making for Fire Potential Index (FPI) and Public Safety
Power Shutoff(PSPS) events. These efforts will consist of three different activities. First,
collaborating with the National Center for Atmospheric Research (NCAR) to evaluate and
validate ensemble weather forecast data. This process will identify outliers and refine the
machine learning methodology used to produce more accurate and reliable forecasts.
Second, the company will expand the number of fire weather stations across its service area. A
centralized data platform will be implemented to manage, store, and provide access to weather
station data in real time. This platform will allow for real-time visualization of observed weather
conditions and offer data download capabilities to support PSPS operations and wildfire
mitigation strategies.
Third, all quality-controlled fire weather station data will be integrated into the company's fire
risk modeling system to enhance its ability to anticipate and respond to wildfire risks. These
advancements in 2025 will build a foundation for future efforts, including the planned adoption
of a full ensemble forecasting system in 2026.
Q 5-Year Cost Estimate for Situational Awareness—Weather Forecasting Activities and Personnel
(2025-2029)
The estimated expenditure for weather forecasting activities(weather forecasting tools,
system development,weather station data services, maintenance,and personnel) is approximately
$2.5 million between 2025 and 2029.
4.5.3. Situational Awareness—Advanced Technologies
Technology-based practices incorporated into Idaho Power's Wildfire Mitigation Plan approach
include—among others—strategic use of AI-enabled wildfire detection cameras,
satellite and aerial imagery to detect vegetation hazards, and pole loading modeling (to assess
the structural integrity of poles).
Regarding cameras, the company initiated a pilot project in 2023 to evaluate the use and
placement of cameras in strategic locations to enhance situational awareness. With input from
state and federal fire responders, Idaho Power developed rigorous evaluation criteria,
which includes learning related to Al capabilities in wildfire ignition detection. Multiple camera
vendors were considered and evaluated based on potential cost-effective solutions. In 2024,
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Idaho Power worked with ALERTWest to install five camera sites in Idaho. Idaho Power is and
will continue to work with federal, state, and local agencies to explore the possibility of
partnering on the installation and ongoing use of cameras, which may lead to cost sharing
and interoperability.
5-Year Cost Estimate for Situational Awareness—Cameras(2025-2029)
0 The estimated expenditure for the pilot evaluation installation of cameras is$190,000 in 2025.
Idaho Power estimates the use of cameras will continue beyond the pilot period and estimates a
total system-wide expenditure of$1.6 million from 2025 through 2029. Idaho Power has deployed
initial camera installations in Idaho and is currently assessing the need,feasibility, and potential
partnership opportunities associated with camera installation in Oregon.
Idaho Power is continuing its pole-loading initiative as part of a pilot project set to run through
2025. This effort involves analyzing the structural integrity of utility poles to ensure they can
withstand various forces, such as wind, weight of equipment, and other environmental factors.
The lessons learned throughout the pilot have benefitted understanding of loading constraints
for poles.
© 5-Year Cost Estimate for Situational Awareness—Pole Loading Modeling and Aerial Imagery
0 Assessment(2025-2029)
The estimated system-wide expenditure to conduct pole loading modeling and aerial imagery
assessment,which includes LIDAR assessment, is$875,000 for 2025 through 2029.
4.5.4. Field Personnel Practices
Idaho Power discusses its field personnel practices in Section 6 of this WMP.
Idaho Power's wildfire mitigation strategy includes procedural measures to reduce potential
ignition and spread of wildfires. Idaho Power developed a Wildland Fire Preparedness and
Prevention Plan (included as Appendix A to this WMP) to provide guidance to Idaho Power
employees and contractors. The plan includes information regarding fire season tools and
equipment available on the job site; daily situational awareness relative to areas where there
is a heightened risk of wildfire; expected actions and mechanisms for reducing on-the-job
wildfire risk, as well as reporting requirements in the event of an ignition; and training and
compliance requirements.
All Idaho Power crews and certain field personnel and contractors performing work on or near
Idaho Power's facilities are required to operate in accordance with the provisions of the
Wildland Fire Preparedness and Prevention Plan and are expected to conduct themselves in a
fire-safe manner. They should be prepared for wildfire by carrying specific tools, including but
not limited to, shovels, Pulaskis, and water for initial suppression. Additionally, Idaho Power's
PSPS program (included as Appendix B to this WMP) includes employees acting as field
observers to report on site conditions as part of the de-energization process. Field observers
are equipped with mobile weather kits that include wind meters, compasses, and satellite
communication devices to report real-time conditions.
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Idaho Power Company Wildfire Mitigation Plan 2025
The preparedness of Idaho Power crews and contractors is a vital component of comprehensive
wildfire risk reduction practices. The incremental investment in field personnel equipment is
focused on additional tools carried by employees working in elevated risk zones. In 2023, Idaho
Power joined the International Wildfire Risk Mitigation Consortium (IWRMC), a group whose
mission is to share lessons learned, best practices, and innovation in wildfire mitigation. Idaho
Power actively participates in monthly workgroup forums for operations and protocols,
asset management, vegetation management, and risk management. These workgroup forums
inform operational preparedness for wildfire season as well as provide insight into global
thinking and advancements in wildfire mitigation.
Q 5-Year Cost Estimate for Situational Awareness—Field Personnel Equipment(2025-2029)
The estimated system-wide expenditure for field personnel equipment(tools, mobile weather kits,
and participation in the IWRMC) is$241,000 between 2025 and 2029.
4.5.5. Transmission and Distribution (T&D) Programs for Wildfire Mitigation
Idaho Power's T&D-related wildfire mitigation activities include expanded asset management
programs and system hardening efforts, discussed in detail in Section 8 of this WMP.
The narratives below provide insight into Idaho Power's consideration and selection of
mitigation, technology, and hardening practices.
4.5.5.1. Annual T&D Patrol, Maintenance, and Repairs
Visual inspections are a critical component of T&D line-related wildfire mitigation efforts. On an
annual basis, Idaho Power uses helicopters for visual aerial inspection of Western Electricity
Coordinating Council (WECC) path transmission lines. Under the WMP, Idaho Power will
continue to use this method of line inspection for all transmission lines located in Tier 3 zones.
Idaho Power strives to complete these inspections prior to the start of the wildfire season;
however, spring weather and snow levels may create access issues and delay the completion
until July in some areas.
Distribution lines located within Tier 3 zones are visually inspected on an annual basis to
identify defects or conditions that may result in an outage or potential ignition. The patrols are
completed by personnel trained in distribution line inspection procedures and with experience
in distribution line construction. Targeted defects include those that could pose an immediate
threat to the continued operation of the line, including, but not limited to, cracked/broken
crossarms, avian nesting hazards, damaged equipment and hardware, floating conductors, and
NESC violations. Like visual inspections for transmission lines, Idaho Power strives to complete
distribution inspections prior to the start of each wildfire season; however, access issues may
delay the completion until July in some areas. Helicopters may not be practical for carrying out
distribution patrols due to greater population, and structural and vegetation density. However,
there are instances where the company may utilize helicopters on a case-by-case basis to
conduct patrols.
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In some areas, Idaho Power utilizes unmanned aerial vehicles (UAV) with high-definition
cameras to aid in inspections. UAV inspections can complement ground-level inspections.
Priority 1 defects are immediately reported and repaired as soon as possible. In 2025, Idaho
Power plans to expand the use of UAV inspections and will work to obtain necessary waivers or
approvals from the Federal Aviation Administration (FAA), including a Beyond Visual Line of
Sight (BVLOS) waiver to allow pilots to operate beyond the direct line of sight. During this time,
the company plans to also evaluate the use of UAVs for PSPS patrols.
Idaho Power has expanded the use of overcurrent protection devices (i.e., reclosers) to isolate
areas of higher wildfire risk from areas with lower risk. This may include installation of new
devices, relocation of existing devices, and/or upgrading remote communication capabilities
(i.e., Supervisory Control and Data Acquisition [SCADA]). Circuit segmentation improves
reliability for customers outside wildfire risk zones during PSPS or Enhanced Protection Settings
(EPS) outage events and improves the capability for Idaho Power to make device changes
remotely in real-time when needed.
Q 5-Year Cost Estimate for Situational Awareness—Annual T&D Patrol, Maintenance, Repairs,
and Segmentation(2025-2029)
The estimated system-wide incremental expenditure for annual T&D patrols, aerial inspections
using drones, maintenance, repairs,and recloser segmentation and advanced relay settings is
$6.1 million from 2025 to 2029.
4.5.5.2. Thermography Inspections
While Idaho Power periodically conducts infrared thermography inspections as part of
reliability and maintenance programs, the company has expanded these inspections in
Tier 3 zones on an annual basis. These inspections are conducted using hand-held and
drone-mounted cameras with thermal-sensing technology and can help identify defects
associated with the overheating of equipment, connections, splices, or conductors.
As part of the thermography inspections, temperature gradients are analyzed to detect
potential problems, and repairs of issues found are prioritized based on their severity.
A combination of Idaho Power personnel and contracted resources are used to perform
thermography inspections. Idaho Power's thermography technician conducts inspections and
coordinates repair activities found by internal and contracted resources. Idaho Power is in the
process of training additional Idaho Power staff to perform this function.
Thermography inspections can uncover problems undetectable to the naked eye. From the
company's perspective, there is not a viable alternative to this practice. The technology enables
more proactive identification of potential issues than would otherwise be possible.
Q5-Year Cost Estimate for Thermography Inspections(2025-2029)
The estimated expenditure for thermography inspections is$1.2 million from 2025 to 2029.
Idaho Power will prioritize the use of this mitigation practice in Tier 3 zones.
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4.5.5.3. Wood Pole Fire-Resistant Wraps
To help improve the resiliency of Idaho Power's transmission system, the company wraps wood
transmission poles with a fire-resistant mesh in wildfire risk zones. The mesh wrap helps
protect the integrity of the pole if it is exposed to fire.
Idaho Power periodically evaluates different products to determine the most cost-effective
approach for protecting existing wood poles from fire. Several products have been considered
and trialed, including short-term, spray-on and paint-on fire retardants, long-term retardants,
and steel wraps. In 2020, the company evaluated a protective mesh wrap and compared the
cost and performance to the alternatives. The evaluation found that the mesh wrap was
approximately 53% less costly than the alternatives and offered the same level of risk
reduction. The decision to use a mesh wrap product was not based solely on cost; other criteria
were considered, including availability of the product, ease of installation, expected protective
life span, and performance when exposed to fire. By all these measures, fire-resistant mesh was
the best solution.
© 5-Year Cost Estimate for Wood Pole Fire-Resistant Wraps(2025-2029)
The estimated system-wide expenditure for applying fire-resistant mesh wraps to transmission
poles in Tier 2 and Tier 3 wildfire risk zones is$1.3 million between 2025 and 2029.
4.5.5.4. Covered Conductor
In 2024, Idaho Power executed a field trial that consisted of the installation of approximately
one mile of covered conductor, including both single-phase and three-phase distribution, in a
Tier 3 wildfire risk zone near Pocatello, Idaho. The objective of the trial was to understand the
feasibility of construction and maintenance, as well as prepare construction standards,
identify required material and equipment, and establish safe and efficient work practices for
potential future implementation. As part of the 2024 field trial, Idaho Power completed written
construction standards for the company and developed and executed a covered conductor
installer training program.
This field trial followed successful completion of a trial in Idaho Power's Skills Training Center in
2023, where field employees got hands-on exposure with installing various covered conductor
materials and installation tools on an isolated low-voltage system.
Idaho Power is in the process of compiling lessons learned during the field installation.
The covered conductor team is additionally analyzing potential co-benefits, including the
potential for improved reliability outside of wildfire season and the potential for reduced
outage restoration costs. Information gathered during this phase will be used to help inform
future implementation approach of covered conductor within Idaho Power's service area.
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Q5-Year Cost Estimate for the Covered Conductor Pilot(2025-2029)
The estimated cost of continuing the pilot in 2025 is$20,000.While this pilot will take place
in Idaho,the lessons from it will extend across the company's service area.
4.5.5.5. Fuels Reduction Shared Stewardship Projects
Throughout 2024, Idaho Power participated in multiple, strategic-partner-initiated fuels
reduction projects that exhibit potential for reducing wildfire risk adjacent to Idaho Power
rights of way (ROW) and wildfire risk zones. The purpose of this effort is to enhance forest
resilience to wildfire, decrease hazardous fuel accumulations near Idaho Power infrastructure,
and increase powerline resiliency while minimizing the risk of ignitions. Established project
partners include Idaho Department of Lands, the U.S. Forest Service (USFS), the U.S. Bureau of
Land Management (BLM), the National Forest Foundation, and local counties. Idaho Power
serves on a cross-utility shared stewardship committee focused on sharing lessons learned from
other western utilities that participate in similar programs and fostering innovation in the
wildfire risk reduction space.
Q 5-Year Cost Estimate for Fuels Reduction Shared Stewardship Projects (2025-2029)
The estimated cost of participation in this effort is estimated at$375,000. Idaho
Power's monetary investment in fuels reduction is leveraged significantly with state
and federal funding.
4.5.5.6. Satellite and Aerial Imagery
Idaho Power's inspection and vegetation management programs include efforts to maintain
clearance from vegetation and objects in relation to transmission and distribution lines. To find
efficiencies and inspect lines from an aerial perspective, Idaho Power is testing satellite and
aerial imagery inspection technologies.
In a pilot project, Idaho Power contracted with a consultant to test the viability of satellite
imagery and Geiger-mode LiDAR for finding potential vegetation encroachments along
distribution and transmission lines. The resulting analysis and field verification showed the
technology still includes random inaccuracies in clearance distances. As a result, the technology
was deemed not yet mature enough for Idaho Power's purposes. Idaho Power will continue
monitoring satellite and similar technologies for future efficiencies, but currently is not
implementing this technology as a program.
Idaho Power also began collecting LiDAR and aerial imagery to analyze all transmission line
clearances on lines that had not been previously analyzed in wildfire prone areas. Data was
collected and classified through 2024. Idaho Power engineers will be modeling the data and
analyzing the imagery for clearances through the summer of 2025. Expenses for this initiative
are summarized under section 4.5.3, Situational Awareness—Advanced Technologies.
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Idaho Power Company Wildfire Mitigation Plan 2025
4.5.6. Enhanced Vegetation Management
Idaho Power's enhanced vegetation management practices are discussed in detail in Section 8.7
of this WMP.
In the initial stage of developing its WMP, Idaho Power conducted an analysis to determine the
potential sources of ignition across the company's service area. Reliability data revealed
vegetation contact as one of the most common causes of outages on Idaho Power's system.
With the goal of eliminating potential ignition sources and to reduce risk, enhanced vegetation
management was recognized as an important part of Idaho Power's WMP.
To prioritize risk reduction from vegetation contact, Idaho Power began to work toward a
three-year pruning cycle along with enhanced vegetation management practices in Tier 3 and
Tier 2 zones. These enhanced practices include pre-fire season vegetation patrols,
more targeted pole clearing and vegetation removal, and additional quality assurance for
vegetation management practices.
The company considered other vegetation management alternatives, including shorter
trimming cycles, longer trimming cycles, and strategies that evaluate each tree individually and
only trim it once it has nearly grown back to the power line (known as "just-in-time trimming").
Each alternative presented challenges or resulted in negative impacts that undermined
potential benefits.
While shorter trimming cycles result in less vegetation being removed during each trimming
cycle, this practice costs more due to the need for more resources and more frequent trimming
of trees near the power lines. In contrast, longer cycles result in less frequent trimming of each
tree but larger amounts of vegetation that must be removed to maintain larger clearance
envelopes around the power lines to accommodate additional years of vegetative growth.
Further, longer trimming cycles create logistical challenges exacerbated by tree biology.
Some trees simply grow faster than a given trimming cycle will accommodate, and the longer
the trimming cycle, the more pervasive this issue may become. Longer cycles that call for heavy
pruning may also lead to hormonal imbalances between a tree's canopy and its root system.
To correct this imbalance, the tree aggressively re-grows new sprouts to quickly replace its lost
canopy. In this regard, heavier pruning results in a faster rate of tree regrowth than normal,
making it even more difficult to consistently maintain longer trimming cycles. Finally, "just-in-
time trimming" is primarily a reactive strategy that ultimately leads to challenges associated
with securing qualified tree-trimming crews, as this ad hoc approach involves hiring crews on
an as-needed basis rather than on a consistent schedule. After evaluating these alternative
approaches, Idaho Power concluded that the goal of striving to maintain a consistent three-year
trimming cycle is the most cost-effective and sustainable strategy to keep vegetation away from
the power lines in a proactive manner.
Alternatives to Idaho Power's vegetation management program include conversion of overhead
distribution circuits to underground and/or the use of covered conductor in densely treed
areas. While undergrounding is used in certain circumstances, widespread undergrounding has
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historically not been found to be a cost-effective expense relative to enhanced vegetation
management. Similarly, while covered conductor may be appropriate in certain circumstances,
widespread deployment is not considered to be a feasible alternative to the enhanced
vegetation management program. That said, the company continues to evaluate
and implement underground solutions and advance its learnings in covered conductor
applications, as appropriate, and as part of its WMP circuit hardening efforts.
Although vegetation management is a sizeable increased wildfire mitigation expense,
performing this work has notable long-term co-benefits, including reduced
vegetation-caused outages in Tier 3 and Tier 2 risk zones. For example, during the 2023 wildfire
season Idaho Power's service area experienced above average number of storm events, high
winds, and lightning compared to previous years. While storm activity was higher, outages
associated with vegetation fell by 27% compared to previous years—indicating that the
company's vegetation management practices are reducing risk. Idaho Power continues to
monitor performance and outage metrics to confirm the success of the enhanced program.
Q5-Year Cost Estimate for Vegetation Management(2025-2029)
The estimated system-wide expenditure for vegetation management is at least$234 million from
2025 to 2029. However,given recent escalations in vegetation management costs across the U.S.,
this figure could increase as Idaho Power continues to strive to meet its cycle and Enhanced
Vegetation Management Program targets.
4.5.7. Communications and Information Technology Customer
Notification Enhancements
Idaho Power's efforts to communicate with customers and the public about wildfire and
mitigation are discussed in detail in Section 10 of this WMP.
Idaho Power considers communication a vital part of its wildfire mitigation efforts.
Communication expenses related to customer and community educational outreach include
advertisements, print media, social media, and public meetings. The purpose of these
communications is to keep customers aware of mitigation and fire-related activities before,
during, and after fire season.
Each year, the company conducts several education campaigns around wildfire including
promoting the company's wildfire mitigation activities and work within communities, providing
awareness and education on preparing for wildfire season, and publicizing ways customers can
reduce fire-ignition potential. The communication is necessary to ensure all customers, whether
they reside wildfire risk zones or not, are aware and educated about PSPS, how the company
will make such decisions, and how customers will be alerted and impacted in such events.
Each year, public meetings are held through various formats, including formal presentations,
open-house-like events, community-based organization collaborations, and virtual town halls
throughout the company's service area. Topics include review of the WMP,
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communication during a PSPS, wildfire prevention, and emergency outage preparedness.
The open-house-like events generally provide the best opportunities to engage with customers.
During PSPS and wildfire events, Idaho Power utilizes communication and event management
tools, including dedicated Idaho Power employees focused on ensuring consistent and accurate
communication, to effectively manage the events and communicate with customers. The 2024
wildfire season, and related PSPS activity, highlighted the need for the company to evaluate
fresh solutions for customer communication and streamline event workflows. The review
resulted in a plan to implement an application to provide situational awareness, event tracking
from initiation through restoration, and automated notifications through integration with the
company's Outage Management System and Communication Tool. This application will
consolidate disparate data sets (fire potential, weather, asset, and other data) in a geographic
display to provide visibility into our forecasted fire risk, allowing timely and accurate decision
making. It will also provide a way to track the status of wildfire zones and devices as it relates to
PSPS events, providing visibility to internal resources that need to take corresponding action,
triggering timely communication to impacted customers, and storing that information for
future reporting and analysis. The company anticipates this application will require ongoing
maintenance and support as included in the associated O&M estimates.
Q 5-Year Cost Estimate for Communication and Customer Notification Enhancements(2025-2029)
The estimated system-wide expenditure for communication expenses is$3.1 million from 2025 to
2029.
4.5.8. PSPS Emergency Preparedness and Technology
Idaho Power carries out emergency operations during PSPS events or when wildfires threaten
infrastructure to ensure public safety, protect critical assets, and minimize disruptions.
The operations are crucial for proactive risk management and coordinated response with public
safety partners and fire agencies. During these events, the company works to minimize the
impacts of PSPS and wildfire-related outages on customers as appropriate, including by opening
community resource centers (CRC) when the company deems them necessary. The company
may partner with county and local emergency managers to coordinate CRCs at accessible
locations, helping to enhance community resilience and potentially decrease the hardships
associated with outages.
When warranted during PSPS and wildfire events, Idaho Power has begun to utilize a dedicated
wildland fire engine and firefighting personnel in certain situations to support on-the-ground
safety and infrastructure protection. The personnel protect critical infrastructure and provide
situational awareness and coordination within the incident command structure during an event
and help to safeguard utility crews working on restoration activities.
The company also utilizes a standby helicopter service to quickly perform pre-storm patrols and
survey de-energized or damaged powerlines following a PSPS or wildfire. The use of a
helicopter enhances Idaho Power's ability to assess risks, ensure safety, and expedite power
restoration, aligning with our goal to continuously strive to decrease impacts of PSPS and
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wildfire for customers. A standby contract structure is needed because Idaho Power has
experienced challenges with helicopter availability during the summer months as local
helicopter resources may be consumed as part of fire response efforts throughout the region.
Idaho Power tested a 6-week standby contract structure in 2024 and intends to evaluate a
longer standby service structure in 2025.
© 5-Year Cost Estimate for PSPS Emergency Preparedness and Technology(2025-2029)
The estimated system-wide expenditure for PSPS emergency preparedness and technology is$3.9
million from 2025 to 2029.
4.5.9. Incremental Capital Investments
Idaho Power's wildfire mitigation efforts include capital investments in system hardening
practices, many of which also provide co-benefits to the company. Capital investment programs
and five-year forecasts are summarized in Table 10. Section 8.4.7.3 additionally summarizes
transmission line rebuild projects planned over the next five years. These projects improve
reliability for customers and increase resiliency of the transmission system from wildfire.
Idaho Power's capital investments for wildfire mitigation are discussed in detail in Section 8
(T&D Asset Management Programs) of this WMP.
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Idaho Power Company Wildfire Mitigation Plan 2025
Table 10
WMP forecasted capital investments
Wildfire Mitigation Forecasted Capital Investments,$000s*
2025 2026 2027 2028 2029 5-Year 5-Year 5-Year
Mitigation Program Description of the Risk Reduction Benefit Planned In Planned In Planned In Planned In Planned In Planned In Total Total
Program Service Service Service Service Service Service Idaho Oregon
Tota I
Systematic Reduced potential of
replacement and equipment failure,utilizing
Overhead Primary upgrades of material and equipment $11,970 $15,004 $17,951 $20,201 $23,656 $88,782 $82,128 $6,654
Hardening Program hardware and with less energy release
and potential of ignition,
equipment increased resiliency
Select conversion of Reduce exposure and
overhead to
Strategic potential of ignition by
Undergrounding
underground locating power lines $2,200 $5,693 $7,070 $12,195 $12,622 $39,780 $38,518 $1,262
conversion in Red underground
Risk Zones
Installation,
relocation,and
Recloser expanded Isolate circuit segments
Segmentation and communication for and improve reliability for $2,000 $1,000 $1,000 $1,000 $1,000 $6,000 $5,480 $520
Communication Automatic enhanced protection
Upgrades Reclosing settings and PSPS
overcurrent
protection devices
Cameras enabled
with artificial Provides early fire
Wildfire Detection intelligence to detection,faster response $95 $95 $- $ $ $190 $120 $70
Cameras detect smoke and time for suppression
notify first activities
responders
Installation of Provides ability to model
Atmospheric Science weather stations to and forecast fire potential $1,602 $1,004 $82 $85 $87 $2,860 $2,622 $238
Weather Stations gain situational and severe weather
awareness conditions for FPI and PSPS
*These are estimates only.The costs may increase or decrease due to such factors as inflation or scope changes.
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Wildfire Mitigation Plan 2025 Idaho Power Company
4.5.9.1. Circuit Hardening
Idaho Power estimates spending approximately$89 million from 2025 through 2029 on circuit
hardening and infrastructure upgrades across its system.
Idaho Power's WMP includes an overhead distribution hardening program for Tier 3 zones.
The program includes systematic replacement of hardware, equipment, and materials to
improve safety and reliability and reduce ignition risk. The first five years of the program have
and continue to be focused on circuits in Tier 3 zones. The company reviews hardening
outcome metrics annually relative to risk reduction and reliability and will assess outcomes to
assist in the determination on whether to expand the program into additional areas.
Prior to developing its WMP, Idaho Power successfully implemented many of the same
hardening measures detailed below as part of the company's reliability program. On average,
outage data and analytics showed customer outages were reduced by approximately 38% in
areas where hardening projects were carried out. With the success of reducing outages,
many of these same activities used to increase reliability were chosen to be part of the WMP to
reduce ignition potential in Tier 3 zones.
Hardening activities and equipment identified in the WMP were evaluated by patrolmen,
troublemen, reliability engineers, and the company's Methods and Materials department to
determine cost-effective solutions that balance overall costs with expected risk reduction.
As an alternative to conducting circuit hardening upgrades, the company considered converting
overhead distribution circuits to underground. While underground conversions of the
distribution system are used in certain circumstances, the upfront cost is estimated to be 2 to
10 times higher than the cost of carrying out hardening work. In general, overhead hardening
efforts provide the benefit of being able to impact a greater number of circuit miles and
customers in a shorter time horizon with less upfront investment than undergrounding.
Additionally, the company is piloting covered conductor as another alternative to traditional
overhead hardening. This pilot program is helping Idaho Power identify technical challenges,
such as compatibility with existing infrastructure and installation and maintenance
requirements. The insights gained are refining the company's designs, construction standards,
and processes for broader implementation. Through this pilot, Idaho Power plans to assess how
each mitigation strategy reduces wildfire risk relative to its cost, labor, and time requirements,
helping inform risk-based decisions when comparing, selecting, and prioritizing mitigation
strategies for the future.
The following summarizes the incremental capital investments the company is making to
harden its system and further reduce wildfire risk. These hardening activities are implemented
on a rolling basis over the course of multiple years consistent with internal prioritization
analysis and scheduling.Overhead distribution infrastructure located in Tier 3 zones is analyzed,
inspected, and hardened as appropriate utilizing the strategies below depending on inspection
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findings, proximity to fuels that may be conductive to wildfires, and risk model data. Idaho
Power plans to complete 90 miles of distribution system hardening in 2025.
• Spark Prevention Units—Porcelain arresters used for overvoltage protection are
changed out with arresters utilizing spark prevention units (SPU). The SPU eliminates
the potential of failure during arrester operation. All distribution arresters on primary
distribution lines in Tier 3 zones are scheduled for replacement by 2027.
• Fiberglass Crossarms—Idaho Power's hardening program includes replacement of wood
crossarms with fiberglass, including the installation of both tangent and dead-end
fiberglass crossarms in Tier 3 zones.
• Small Conductor—Idaho Power has analyzed the possible risk associated with small
conductor relative to the potential for breakage. As a result of this exercise,
Idaho Power has targeted overhead distribution conductor smaller than #4 ACSR
(copper and 3SS conductor), which includes approximately 60 miles or more in Tier 3
zones. Conductor losses were analyzed and showed replacing the conductor will result
in an approximately 50% reduction of line losses, resulting in co-benefits for the
company and customers in terms of greater reliability and line loss improvements.
• Porcelain Switches—Idaho Power's Outage Management System (OMS) and feedback
from field personnel revealed potential benefits of switches made from material other
than porcelain. Therefore, porcelain switches installed in Tier 3 zones will be changed
out with cutouts featuring Ethylene Propylene Diene Monomer Rubber (EPDM).
Idaho Power's Methods and Materials department trialed different cutout switches
made of different material, including silicone and polymer, to find the most
cost-effective and reliable solution. The results of the trial highlighted the potential for
avian issues with silicone (i.e., ravens tended to eat the silicone), and the cost of EPDM
versus polymer was nearly equivalent. The financial analysis determined EPDM would
preserve the integrity of the insulator body, prevent outages, and provide an estimated
savings of$10,798 per year over silicone.
• Avian Protection—Idaho Power employs several different protection measures the
protect wildlife including, but not limited to, covers, insulated conductor, diverters,
perches, nesting platforms, and structural modifications, as appropriate. The company
has an extensive history working with manufacturers of animal guards/covers and
regularly seeks new solutions for avian issues to prevent mortalities, increase reliability,
and eliminate other risks. The company's Avian Protection Plan (APP) was developed in
the mid-2000s, and many of the practices identified in the APP are used for wildfire
mitigation in Tier 3 and Tier 2 zones. For example, new wildlife guards were recently
developed and installed in conjunction with the installation of new power fuses and
SPUs. Idaho Power consulted with different manufacturers to develop new products to
accomplish the dual goals of avian protection and wildfire mitigation. Solutions are
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determined on a case-by-case basis depending on the specific location, the type and
extent of avian presence, and other relevant factors.
4.5.9.2. Overhead to Underground Conversions
An aspect of Idaho Power's system hardening program is the select conversion of overhead to
underground distribution lines in wildfire risk zones. Areas selected for underground conversion
are based on the results of risk quantification and modeling work, feedback from local fire
officials, fire history, PSPS likelihood based on historic weather conditions, and consideration of
infrastructure access and public egress. In 2024, the company identified seven miles of
overhead powerlines for underground conversion through 2026 and began developing designs.
Q 5-Year Cost Estimate Overhead to Underground Conversions(2025-2029)
Idaho Power estimates spending approximately$40 million from 2025 through 2029 on converting
overhead distribution circuits to underground construction.
4.5.9.3. New Underground Construction
Customer growth and new developments in wildland urban interface (WUI) areas present
challenges for Idaho Power when working to decrease wildfire risk. As people increasingly move
into areas with more wildfire risk, the company faces the dual challenge of expanding
infrastructure to serve customers while remaining mindful of wildfire risk. Additionally,
underground systems are less affected by extreme weather conditions, such as strong winds,
falling trees, and lighting, and provide a greater level of resiliency and risk reduction. As a
result, Idaho Power will evaluate new developments to determine if near-term risk levels
warrant underground construction at the onset of a project; specifically, the company may
consider a new development's location, wildland fuels, suppression and response capabilities,
and egress/ingress routes when determining if underground construction is warranted. The risk
reduction benefits, and cost of underground construction will be explored in each instance, and
the company may choose to pay the difference between new overhead construction and
underground at its discretion.
© 5-Year Cost Estimate for Underground Construction(2025-2029)
Idaho Power estimates spending approximately$15 million from 2025 through 2029 on new
underground construction in wildfire risk zones.This amount will ultimately be dictated by new
development activity in wildland urban interface or wildfire prone areas.
4.5.9.4. Recloser Segmentation
Segmentation is a strategy involving the placement of overcurrent protection devices,
called reclosers, to isolate or segment areas of higher wildfire risk from areas with lower risk.
The goal of segmentation is to improve the reliability for customers outside wildfire risk zones
by limiting their exposure to PSPS and EPS events. Reclosers provide a point of de-energization
for PSPS and are also used to implement EPS on days having higher fire potential to limit the
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risk of ignition. Segmentation work includes installing new SCADA-operated reclosers,
upgrading existing reclosers with communications and SCADA control, or relocating
existing reclosers.
© 5-Year Cost Estimate for recloser segmentation(2025-2029)
Idaho Power estimates spending approximately$6 million from 2025 through 2029 on the
installation, relocation,and communication upgrade of reclosers.
4.5.9.5. Transmission Steel Poles
Idaho Power's transmission construction standards utilize steel poles and structures for new
line construction at voltages of 138-kV and above. This approach is designed to enhance
wildfire mitigation, improve transmission line resiliency, reduce future rebuilding costs after fire
events, and ensure greater reliability for customers. While steel poles are the preferred choice,
IPC may exercise its discretion to utilize wood poles when the use of wood poles is more
feasible than steel poles, including based on factors such as limited supply or availability of steel
poles, engineering specifications, right-of-way constraints, permitting requirements, and
project timelines.
4.5.9.6. Line Monitoring Technology(Pilot)
As part of Idaho Power's ongoing commitment to enhancing wildfire mitigation strategies, the
company will begin a pilot project incorporating line monitors into its distribution system in
wildfire prone areas. This innovative initiative underscores Idaho Power's dedication to
enhancing grid reliability, safety, and operational efficiency, particularly in areas with elevated
wildfire risk.
Line monitors are devices installed on overhead powerlines that use advanced sensing
technologies to provide real-time data about the condition and performance of the electrical
grid. The integration of line monitors into wildfire mitigation efforts may provide multiple
benefits including fault detection, historical perspective on fault locations, and transient
capture capabilities. As part of the pilot, Idaho Power will begin leveraging their advanced
capabilities, to help address potential risks proactively.
© 2-Year Cost Estimate for the Line Monitor Pilot Project(2025-2026))
Idaho Power estimates spending approximately$385,000 from 2025 through 2026 on the
installation of line monitors.
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5. Situational Awareness
5.1. Overview
Visibility and readily available access to current and forecasted meteorological conditions and
fuel conditions is a key aspect of Idaho Power's wildfire mitigation strategy. Meteorological and
fuel conditions can vary significantly across Idaho Power's service area. Idaho Power leverages
its internal Atmospheric Science department's modeling/forecasting capabilities, its existing fire
weather stations, and publicly available weather/fuel data to develop projections of current
and future wildfire potential across Idaho Power's service area. This wildfire
potential information is then available to operations personnel to factor into operational
decision-making.
5.2. Fire Potential Index
Idaho Power has developed a Fire Potential Index (FPI) tool based on original work completed
by San Diego Gas and Electric (SDG&E), the National Forest Service, and the National
Interagency Fire Center (NIFC) and modified for Idaho Power's Idaho and Oregon service area.
This tool is designed to support operational decision-making to reduce fire threats and risks.
This tool converts environmental, statistical, and scientific data into an easily understood
forecast of the short-term fire potential, which could exist for different geographical areas in
the Idaho Power service area. The FPI is issued for a seven-day period to provide for planning of
upcoming events by Idaho Power personnel.
The FPI reflects key variables, such as the state of native vegetation across the service area
("green-up"), fuels (ratio of dead fuel moisture component to live fuel moisture component),
and weather (sustained wind speed and dew point depression). Each of these variables is
assigned a numeric value, and those individual numeric values are summed to generate a Fire
Potential value from 0 to 16, each of which expresses the degree of fire potential expected for
each of the 7 days included in the forecast. The FPI scores are grouped into the following
index levels:
• Green: FPI score of 0 through 11 indicates lower potential for a large fire to develop and
spread, as there is normal vegetation and fuel moisture content as well as weak winds
and high relative humidity.
• Yellow: FPI score of 12 through 14 indicates an elevated potential for a large fire to
develop and spread, as vegetation and fuel moisture content are below normal,
along with moderate winds and lower than normal relative humidity.
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• Red: FPI score of 15 through 16 indicates a higher potential for a large fire to develop
and spread, as vegetation and fuel moisture content are well below normal, along with
strong winds and low relative humidity.
Fire Potential Index(FPI) Category
Normal Elevated :UHigher
FPI Range 0 to 11 12 to 14to 16
The state of native grasses and shrubs, or the Green-Up Component, of the FPI is determined
using satellite data for locations throughout Idaho Power's areas of interest. This component is
rated on a 0-to-5 scale ranging from very wet (or "lush") to very dry (or "cured"). The scale is
tied to the Normalized Difference Vegetation Index (NDVI), which ranges from 0 to 1,
as follows:
Green-Up Component
Very Very
NDVI Wet/Lush: 0.64 to 0.60 0.59 to 0.55 0.54 to 0.50 0.49 to 0.40 Dry/Cured
1.00 to 0.65 0.39 to 0.00
Score 0 1 2 3 4
The Fuels Component (FC) of the FPI measures the overall state of potential fuels that could
support a wildfire. Values are assigned based on the overall state of available fuels (dead or
live) for a fire using the following equation:
FC = FD/ LFM
Where FC represents Fuels Component in the scale below, FD represents 100-hour Dead Fuel
Moisture (using a 1-to-3 scale), and LFM represents Live Fuel Moisture (percentage). This data
will be collected from satellite sources and regional databases supported by state and
federal agencies.
The product of this equation represents the fuels component reflected in the FPI as follows:
Very Wet Very Dry
0 1 2 3 4
The weather component of the FPI represents a combination of sustained wind speeds and
dew-point depression as determined using the following scale. This data is sourced from the
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WRF products produced by Idaho Power using its High-Performance Computing system.
In addition to the HPC-system-produced WRF data, several national level meteorological
products are used. These products include regional weather observations used to validate
model information.
Dewpoint 55 mph 6 to 11 mph 12 to 18 mph 19 to 25 mph 26 to 32 mph >_33 mph
Depression Wind
>_50°F 4 4 4 5
402F to 492F 3 3 4 4 5 5
302F to 392F 3 3 3 4 4
202F to 292F 3 3 3 3 3 4
102F to 192F 2 2 2 2 2 3
<10°F 1 1
5.3. FPI Review and Evaluation
The FPI process is reviewed annually after completion of the fire season with consultation of
interested parties (e.g., Load Serving operator, line crews, and others). Evaluation of the FPI
process is used to assess and validate Idaho Power's wildfire preparedness approach.
5.4. Forecast Ensemble
In 2024 Idaho worked with the National Center of Atmospheric Research (NCAR) to begin
development of a multi-model ensemble of atmospheric models focused upon providing a
higher level of accuracy and precision of forecasts (both spatial and temporal) while also
allowing for the development of probabilities for when, where, and what magnitude of events
may occur by being able to better account for the variability between model realizations and
other atmospheric and environmental complexities. Additionally in 2025 Idaho Power upgraded
its High Performance Computing system's computing capabilities to run the multi-model
ensemble. In 2025 IPC will continue working with NCAR to complete calibration and verification
of the ensemble forecasting system with full implementation in Idaho Power's fire weather
forecasting process expected to occur in 2026.
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6. Mitigation—Field Personnel Practices
6.1. Overview
A component of Idaho Power's wildfire mitigation strategy is to prevent the ignition and spread
of wildfires due to employee work activities. Idaho Power developed the Wildland Fire
Preparedness and Prevention Plan (Appendix A) to provide guidance to Idaho Power employees
and contractors working in locations and under conditions where there is a heightened risk of
wildfire. All Idaho Power crews and certain field personnel performing work on or near Idaho
Power's facilities are expected to operate in accordance with the Plan and continue to conduct
themselves in a fire-safe manner.
6.2. Wildland Fire Preparedness and Prevention Plan
The Wildland Fire Preparedness and Prevention Plan informs Idaho Power personnel and its line
construction contractors about the following factors:
• Annual fire season tools and equipment to be available when on the job site
• Daily situational awareness, including weather conditions, regarding locations where
there is a heightened risk of wildfire
• Expected wildfire ignition prevention actions while working, and reporting instructions
in the event of fire ignition
• Training and compliance requirements
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7. Mitigation—Operations
7.1. Overview
A component of Idaho Power's wildfire mitigation strategy is to continue safe and reliable
operation of its transmission and distribution (T&D) lines while also reducing wildfire risk.
These operational practices primarily center around the following:
• Temporary operating procedures for transmission lines during the fire season.
• Temporary operating procedures for distribution lines in wildfire risk zones during the
fire season.
• An operational strategy for T&D lines during periods of elevated wildfire risk during the
fire season
• A public safety power shutoff(PSPS) strategy for Idaho Power's service area and
transmission corridors
7.2. Operational Protection Strategy Definitions
Operational protection strategies were developed to reduce the probability of ignition during
fault events on Idaho Power's distribution system. Starting in 2024, the company implemented
a pilot distribution protection strategy during the wildfire season consists of two modes:
1) Enhanced Protection Settings (EPS) Mode 1
2) Enhanced Protection Settings (EPS) Mode 2
Enhanced Protection Settings (EPS) are enabled in automatic reclosing (AR) protective devices
on feeders protecting high-risk fire zones. AR protective devices include feeder relays (at head
end of feeder) and reclosers. The definitions of the various protection modes are as follows:
EPS Mode 1: Auto-reclose turned off. This allows only a single trip, which eliminates traditional
re-energizations to test the line, reducing chances of fire ignitions.
EPS Mode 2: Auto-recloser turned off and trip settings set to instantaneous lockout. This is a
much more sensitive setting that will cause the AR device to lockout prior to most fuses.
Mode 2 is designed to minimize the fault energy, further reducing the risk of fire ignition.
See section 7.4 and 7.5 for information on how and when EPS is applied.
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The company plans to continue to evaluate and evolve protections schemes and strategies.
Lessons learned from benchmarking and data analysis will continue to be used to inform Idaho
Power's system protection strategies.
7.3. Transmission Line Operational Strategy
7.3.1. Fire Season Temporary Operating Procedure for Transmission Lines 115
kilovolt (kV) & Above
Each year, typically in May, leadership within Idaho Power's Load Serving Operations (LSO)
department updates and issues its Fire Season Temporary Operating Procedure. The purpose of
this temporary operating procedure is to provide LSO employees with guidelines for operating
transmission lines during the summer fire season. The procedure aims to reduce wildfire risk
through practices relating to information collection, notification, and procedures for
testing/closing in on locked-out transmission lines.
7.3.2. Tier 3 Zone Transmission Operational Strategy 69 kV& Below
During wildfire season, Idaho Power determines a daily FPI as described in Section 5 of this
WMP. The FPI informs the transmission line operational strategy for those lines owned,
operated, and located in Tier 3 zones. These lines will be operated in normal settings mode but
with no "testing"19 of a line that may have "locked out" during the time of a red FPI. In the
event of a fault on the specified transmission line(s) during a red FPI, the line will operate as
normal and may "lock out," at which time the line(s) will either need to be patrolled before
"testing" or wait until the FPI level drops out of the red category prior to being re-energized.
7.4. Distribution Operational Strategy and EPS
During wildfire season, Idaho Power determines a daily FPI as described in Section 5 of this
WMP. The FPI informs the distribution line operational strategy for those lines located in and
adjacent to wildfire risk zones. EPS settings are activated remotely from our Distribution
Control Center when remote control is available through Supervisory Control and Data
Acquisition (SCADA). When SCADA control is not available on an AR device, qualified company
personnel must enable the EPS modes manually at the AR device. EPS settings—both Mode 1
and Mode 2—are activated by wildfire risk zone at each of the AR devices protecting the zone.
9 Transmission line"testing"refers to the human act of re-energizing a line without completing a physical field patrol or observation of a line.
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EPS Mode 1 turns off auto reclosing. This allows only a single trip, which eliminates traditional
re-energizations to test the line, reducing chances of arcing and sparking. EPS Mode 1 is
generally operated as a seasonal setting. It is activated when fuel conditions reach a reach a
cured state resulting in increased fire potential. Mode 1 remains in effect until fuel conditions
change and there is decreased fire potential as established by the company's Atmospheric
Science team.
EPS Mode 2 involves auto-reclosing turned off and trip settings set to instantaneous lockout.
This is a much more sensitive setting that will cause the automatic reclosing device to lockout
prior to most fuses. Mode 2 is designed to minimize the fault energy, further reducing the risk
of arcing and sparking. Mode 2 is enabled on SCADA and non-SCADA AR devices protecting
wildfire risk zones during days of higher fire potential. The criteria to activate Mode 2 generally
includes a forecasted FPI of 15 or higher (red) and meeting or exceeding zone-specific wind
criteria established for each zone based on historic climatology. Mode 2 may be enabled on a
case-by-case basis for other factors, including, but not limited to, if the National Weather
Service issues a Red Flag Warning that covers a wildfire risk zone(s).
Mode 2 applies only to AR devices that have fast trip or instantaneous trip capability. Not all AR
devices protecting wildfire risk zones currently have this capability. The company has initiated a
multi-year project to upgrade all AR devices impacting wildfire risk zones with EPS Mode 2
capability and SCADA controls. Table 1, located in the Executive Summary, details 2025 goals
for upgrades.
7.5. PSPS
7.5.1. PSPS Definition
PSPS, as used in this WMP, is defined as the proactive de-energization of electric transmission
and/or distribution facilities during extreme weather events to reduce the potential of those
electrical facilities becoming a wildfire ignition source or contributing to the spread of wildfires.
The concept is as follows—if extreme weather events can be predicted far enough in advance,
the resulting proactive line de-energization before the forecasted weather conditions
materialize could mitigate the risk of a wildfire caused by Idaho Power's electric transmission
and/or distribution facilities. A PSPS event can result in customer impact and generates
extensive planning and strategy leading up to, during, and after a PSPS event.
PSPS is not the practice of de-energizing lines in the following types of situations:
• Unplanned de-energization of lines required for emergencies and during outage
restoration situations.
• Planned line or station work activities that require a planned outage (Idaho Power
currently has a planned outage customer notification process in place for this).
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• Reactive de-energization of electric transmission and/or distribution facilities,
which may be either at Idaho Power's determination or at the request of fire managers
(e.g., Bureau of Land Management [BLM], U.S. Forest Service, or other fire-fighting
managers) in response to existing/encroaching wildfire threatening to burn into
such facilities.
• Automated de-energization of electric transmission and/or distribution facilities due to
smoke/fire from an existing fire causing a fault on the line.
Idaho Power will continue its current de-energization practices in the above referenced,
and comparable situations. Such outage situations are not defined as PSPS events in the
context used here and, as a result, would not trigger PSPS protocols.
7.5.2. PSPS Plan
Idaho Power developed a PSPS Plan (see Appendix B) that operates in parallel with its wildfire
mitigation strategy. Although the wind patterns in Idaho Power's service area are generally of a
much lower sustained velocity and often less predictable (i.e., micro-bursts) than other utilities'
service areas where PSPS has most frequently been utilized (i.e., California), the company's
PSPS Plan generally follows industry best practices by considering other utilities' PSPS plans and
incorporating wildfire risk and other considerations specific to Idaho Power's service area.
While a PSPS event is more probable in wildfire risk zones, Idaho Power retains the ability to
utilize PSPS anywhere throughout the service area. The decision regarding PSPS is based on
several dynamic factors, and each weather event is unique.
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8. Asset Management and Inspection Initiatives
8.1. Overview
Idaho Power's wildfire mitigation strategy relies in part on its various asset management
programs, including asset inspections, to maintain safe and reliable operation of its
transmission and distribution (T&D) facilities in reducing wildfire risk.
8.2. T&D Asset Management and Inspections
Idaho Power implements and continuously evaluates a set of asset management and inspection
initiatives. Fundamental to these efforts is the continual research into industry best practice
and strategic piloting of emerging technologies and approaches to complement and improve
Idaho Power's core asset management strategy. Idaho Power's approach for supporting wildfire
prevention and mitigation through asset management and inspection initiatives is summarized
in Table 11 and subsequently detailed throughout this section. Table 12 provides detail on Idaho
Power's assets relative to wildfire risk zones.
Table 11
Asset management and inspection initiatives
Wildfire Mitigation Asset Management Inspection Initiatives
Transmission Distribution
Aerial Visual Inspection Program Ground Detail Inspection Program(enhanced)
Ground Visual Inspection Program Wood Pole Inspection and Treatment
Detailed Visual Inspection Program Wood Pole Fire Protection Program
Wood Pole Inspection and Treatment Program Line Equipment Inspection Program
Cathodic Protection and Inspection Program Thermal Imaging Inspections
Thermal Imaging Inspections Overhead Primary Hardening Program
Wood Pole Wildfire Protection Program
Steel Pole Program
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Table 12
Service area asset overview20
Total Tier 3 Tier 2 Total Tier 3 Tier 2
Type of Equipment Idaho Idaho Idaho Oregon Oregon Oregon
Substations 294 9 11 44 2
Power Generation Facilities 19 - - 3 - -
Overhead Transformers 120365 6722 5588 10209 295 322
Reclosers 1078 60 35 138 2 2
Voltage Regulators 1226 70 45 128 3 0
Capacitor Banks 1707 22 30 79 1 -
Wood Poles(transmission) 31,390 530 1,850 7,222 - 200
Steel Poles(transmission) 9697 197 814 646 1
Transmission Towers 2,369 144 227 166 - 1
Overhead Expulsion
Prevention Line Fuses*
49283 2139 1925 2268 45 62
Overhead Standard Line
Fuses* 3449 117 130 181 2 2
*Counted as individual
fuses
8.3. Inspection and Correction Timeframes
Asset management inspections allow personnel to look for potential defects, which, if found,
are documented, categorized, and scheduled for repair based on priority designation.
Quality assurance inspections for new construction are performed annually across the service
area to enhance the safety of the public and verify the quality of new construction is consistent
with the National Electrical Safety Code (NESC). Work orders are randomly selected for
inspection, and deficiencies are recorded and corrected based on the priority level. The results
of the inspections are shared with regional field workers to help foster learning and ensure
construction meets current standards. In addition to randomly selected inspections,
thermography technicians also perform annual inspections in Tier 3 zones, providing a degree
of quality assurance for previous inspections.
Idaho Power continues to evaluate the use and efficiency of emerging and alternative
technologies to supplement detailed ground inspection. In 2025 Idaho Power plans to expand
0-See Table 5 for overhead conductor line miles.
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the use of unmanned aerial vehicle (UAV) inspections and will work to obtain necessary waivers
or approvals from the Federal Aviation Administration (FAA), including a Beyond Visual Line of
Sight (BVLOS) waiver to allow pilots to operate beyond the direct line of sight, possibly
enhancing the efficiency of inspections.
Table 13 summarizes Idaho Power's inspection initiatives and frequency with respect to wildfire
risk zones.
Table 13
Summary of asset inspections and schedules by state and zone
Inspection Interval
Idaho Oregon Idaho Oregon Idaho Oregon
Asset Inspection Type Non-Risk Zone Non-Risk Zone Tier 2 Tier 2 Tier 3 Tier 3
Transmission Defect Inspections
Visual* Annually Annually Annually Annually Annually Annually
Detailed 10 Years 10 Years 10 Years 10 Years 10 Years 10 Years
Groundline(Wood Pole Test and Treat) 10 Years 10 Years 10 Years 10 Years 10 Years 10 Years
Infrared Patrol None None None None Annually Annually
Distribution OH Defect Inspections
Visual/Detailed* 3 Years 2 Years 3 Years 2 Years 3 Years 2 Years
Groundline(Wood Pole Test and Treat) 10 Years 10 Years 10 Years 10 Years 10 Years 10 Years
Wildfire Mitigation/Potential Ignition
Source Patrol* None None None Annually Annually Annually
Infrared Inspections None None None Annually Annually Annually
*Includes Ignition Prevention Inspection consistent with Oregon Administrative Rules in Chapter 860,Division 24.
8.4. Transmission Asset Management and Inspection Initiatives
Idaho Power's transmission asset management inspections programs include condition-based
aerial visual inspections, ground visual inspections, detailed visual (generally using
high-resolution photography) inspections, transmission wood pole inspection and treatment,
and cathodic protection.
8.4.1. Aerial Visual Inspection Program
Annually, Idaho Power uses helicopters to assist qualified Idaho Power personnel in the aerial
visual inspection of transmission lines identified as Western Electricity Coordination Council
(WECC) Path Lines. This method of line inspection is also part of Idaho Power's Wildfire
Mitigation patrols and is used on an annual basis pre-wildfire season for non-WECC
transmission lines located in Tier 3 zones. UAVs with high-definition cameras are also being
used in certain situations to inspect facilities on these lines.
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Idaho Power Company Wildfire Mitigation Plan 2025
8.4.2. Ground Visual Inspection Program
Annually, qualified Idaho Power personnel (i.e., trained in transmission line inspection
procedures and experienced in transmission line construction) complete ground visual
inspections of all transmission lines. Ground patrols are completed using four-wheel-drive
vehicles, all-terrain vehicles (ATV), utility terrain vehicles (UTV), and/or on foot.
These inspections support the identification of potential line defects that are documented and
scheduled for repair based on defect classification.
8.4.3. Detailed Visual(High-resolution Photography) Inspection Program
In addition to the annual inspections and associated maintenance, Idaho Power also completes
detailed visual inspections generally utilizing high resolution photography. This inspection is
typically completed using helicopters, UAVs, and contracted professionals operating
high-definition cameras. If potential line defects are noted, they are scheduled for repair
consistent with defect classification. The detailed visual inspections are completed on a 10-year
cycle in conjunction with the 10-year cycle of wood pole ground line inspection and treatment.
8.4.4. Thermal Imaging (Infrared) Inspections
Idaho Power annually inspects transmission lines and equipment within Tier 3 zones using
thermal imaging (infrared) cameras. Compromised electrical connections and overloaded
equipment may be identified using thermal imagery. Identified risks will be prioritized and
mitigated consistent with defect classification.
8.4.5. Wood Pole Inspection and Treatment Program
All wood poles are visually inspected, sounded, and bored for defects and decay on a 10-year
cycle. Poles are categorized according to the following:
• Reported: Any wood pole inspected and found to be installed within 10 years of the
manufactured date or last inspection date.
• Treated: Any wood pole inspected and found to be installed 11 years or more prior
to the inspection date and determined to be in sound enough condition to
warrant treatment.
• Rejected: Any wood pole determined to fit the following criteria:
• Has less than 4 inches of shell at 48 inches above the ground line; or
• Less than 2 inches of shell at 15 inches above the ground line; or
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• Less than 2 inches of shell at the ground line; or
• Is deteriorated and does not meet minimum strength criteria; or
• Fails a visual inspection.
Rejected poles are categorized as either reinforceable with steel or
non-reinforceable and are to be replaced.
• Visually Rejected: Any wood pole that has been damaged (i.e., burned, split, broken,
hit by a vehicle, damaged by animals, etc.) above the ground line to such an extent as to
warrant rejection and that cannot be further tested to determine priority status.
• Sounded, Bored, and Treated: Any wood pole set in concrete, asphalt, or solid rock
10 years or more prior to the inspection date is internally treated. Internal treatment
involves fumigating the good wood and flooding the voids with fumigant.
8.4.6. Cathodic Protection and Inspection Program
Cathodic protection systems are employed on select steel transmission towers. These systems
use either an impressed current corrosion protection system (ICCP) or direct-buried sacrificial
magnesium anodes. Included in Idaho Power's tower maintenance plan, every 10 years,
structure-to-soil potential testing is performed on select towers with direct-buried anodes.
For ICCP systems, rectifiers and ground-beds are tested to ensure they are functioning properly.
Based on test results, repairs and adjustments are completed. Each year all rectifiers are
inspected, and direct current (DC) voltage and DC current readings noted.
8.4.7. Transmission Asset Protection
8.4.7.1. Wood Pole Wildfire Protection Program
To help improve the resiliency of Idaho Power's transmission system and the company's
wood transmission poles, Idaho Power seeks to wrap certain wood transmission poles with a
fire-resistant mesh. The mesh wrap helps protect the integrity of the pole if it is exposed to fire.
Idaho Power is in the process of installing mesh wrapping on transmission wood poles located
in the Tier 3 and Tier 2 zones and plans to install mesh on approximately 704 transmission poles
in 2025. The company retains the option to utilize mesh in additional areas outside wildfire risk
zones, including areas that may exhibit frequent fire return intervals.
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8.4.7.2. Transmission Steel Poles
Idaho Power uses steel poles or structures for new transmission line construction projects built
to 138-kV standards and above to minimize wildfire damage and improve transmission line
resilience. Wood poles may be used on 138-kV structures for emergency and maintenance
replacements based on the specific engineering, right-of-way (ROW), permitting,
and scheduling requirements for each project.
8.4.7.3. Transmission Line Rebuild Projects
Idaho Power takes proactive steps to repair or replace transmission line components
on an ongoing basis as part of asset management and aging infrastructure assessments.
Annually, inspection activities inform maintenance needs with short- and long-term plans
developed to manage line assets. In some cases, lines are selected to be rebuilt in the future to
increase capacity, reliability, or improve safety. Wildfire risk and the location of transmission
lines are considered as part of the prioritization of transmission line rebuild projects. Table 14
summarizes transmission line rebuild projects planned over the next five years. These projects
will improve reliability for customers and increase resiliency of the transmission system from
wildfire. Construction schedules and material lead times may change and adjust the in-service
dates shown.
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Table 14
Transmission line rebuild projects, estimated planned investment ($000s) and timeline
Transmission Line Description 2025 2026 2027 Planned 2028 Planned 2029 5-Year Planned 5-Year
Planned Planned Cost Cost Planned Cost Idaho Planned Cost
Cost Cost Cost Oregon
Line 412—Rebuild of Rebuild the Boise Bench to $10,393 $10,393
existing Boise Bench to Emmett 138-kV line using
Emmett 138-kV transmission steel structures instead of
line,Idaho wood as identified in
WMP.
Line 433—Rebuild existing Rebuild the existing 138-kV $246 $626 $8,022 $8,894
Wood River to Ketchum transmission line from
138-kV transmission line, Wood River to Ketchum
Idaho Substation,Idaho,using
steel structures instead of
wood as identified in
WMP.
Line 204—Rebuild Boise to Rebuild existing 69-kV line 1p $39 $103 $14,726 $2,112 $16,980
Emmett Junction,the Cairo structures to 138-kV
to Fruitland tap to 138-kV capabilities,using steel
specifications,Idaho structures instead of wood
as identified in WMP.
Ammdw
Line 328—Rebuild Existing Rebuild existing 69-kV line $139 $127 $25,482 $25,811 $1 $51,560
Emmett to Warm Lake 69-kV structures to 138-kV
line to 138-kV specifications, capabilities using steel
Idaho structures instead of wood
as identified in WMP.
Line 423—Rebuild the Rebuild the Ontario $159 $11,734 $13,417 $25,467
Ontario to Huntington 138- Substation to Huntington
kV transmission line,Oregon Substation,Oregon,with
tubular steel 138-KV H-
frame structures.
Line 701—Rebuild from Replace wood structures $65 $621 $354 $201 $26,015 $27,256
Quartz Substation to La with tubular steel 230-kV
Grande 230 kV H-frame structures.
Line 906 Boise Bench to Replace poles,cross arms, $1,676 $1676
Midpoint substation 230 kV, and insulators identified
Idaho during the Pole Inspection
and Groundline Treatment
Program and the annual
routine Line Patrols.
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Idaho Power Company Wildfire Mitigation Plan 2025
Transmission Line Description 2025 2026 2027 Planned 2028 Planned 2029 5-Year Planned 5-Year
Planned Planned Cost Cost Planned Cost Idaho Planned Cost
Cost Cost Cost Oregon
Line 906—Boise Bench to Rebuild line from Boise $16 $37 $0 $6,945 $6,998
Midpoint Substation,230 kV Bench Substation to
#2,Idaho Midpoint Substation,
Idaho.Wood structures
will be replaced with
tubular steel 230-kV H-
frame structures.
Line 908—Rebuild the Rebuild the Pallette to $7,737 $8, qW
Pallette to Imnaha 230-kV Imnaha 230-kV line,
transmission line,Oregon, Oregon,with tubular steel
currently in preliminary H-frame structures.
scoping
T902—Rebuild the Boise Phase two of four phases $1,791 $1,791
Bench to DRAM Substation of the transmission line
segment on the Boise Bench rebuild.The line is to be
to DRAM to Midpoint#1 constructed using steel
230-kV line(Phase 2),Idaho H-frame structures.
Line 902—Rebuild the Phase three of four phases $9,045
Mountain Air Wind Park to of the transmission line
Rattle Snake Station rebuild.The line is to be
segment on the Boise Bench constructed using steel
to DRAM to Midpoint#1 H-frame structures.
230-kV line(Phase 3),Idaho
Line 902—Rebuild the Phase four of four phases $1,600 $19,988 $15,788 $6,944 $44,320
Midpoint to Mountain Air of the transmission line
Wind Park Station segment rebuild.The line is to be
on the Boise Bench to DRAM constructed using steel
to Midpoint#1 230-kV line H-frame structures.
(Phase 4),Idaho
Line 410—Rebuild Lucky Rebuild with steel poles $7,730 $17,868 $25,598
Peak Junction to Mountain instead of wood.
Home Junction segment of
Lucky Peak to King Line
138-kV line rebuild,Idaho
Line 410—Rebuild the Black Rebuild with steel poles $7,568 $7,568
Mesa Substation to Cassia instead of wood.
Wind Park segment of Lucky
Peak to King 138-kV line
rebuild,Idaho
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Wildfire Mitigation Plan 2025 Idaho Power Company
Transmission Line Description 2025 2026 2027 Planned 2028 Planned 2029 5-Year Planned 5-Year
Planned Planned Cost Cost Planned Cost Idaho Planned Cost
Cost Cost Cost Oregon
Line 410—Rebuild DRAM to Rebuild with steel poles $3,203
Lucky Peak of the 138-kV instead of wood.
line rebuild,Idaho
Line 410—Rebuild Mountain Rebuild with steel poles $25 $25
Home Junction to Black instead of wood.
Mesa segment of Lucky
Peak to King 138-kV line
rebuild,Idaho
Line 925—Rebuild Lucky Rebuild with steel poles $5,475
Peak Junction to segment of instead of wood.
the Lucky Peak to King
138-kV line rebuild,Idaho
Line 401—Relocate line Remove 2,880'of 138-kV $43 $444 $15 $502
terminal from CLIF to line and rebuild new
RMVW,Idaho section using steel
structures instead of wood
as identified in WMP and
WMP IPUC application.
Line 403—Minidoka Loop Replace structures 1-4
138 kV.Replace Structures with steel.There are
1-4 with steel,Idaho currently 16 wood poles in
these 4 structures.
Line 407—Relocate line Remove 3,582'of 138-kV $35 $110 $213 $358
terminal from CLIF to line and rebuild new
RMVW,Idaho section using steel
structures instead of wood
as identified in WMP and
WMP IPUC application.
Line 702—Midpoint—Hunt This work is proposed to
230 kV.Rebuild 3 structures be completed during the
with steel structures,Idaho 10-year maintenance in
2028.
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Idaho Power Company Wildfire Mitigation Plan 2025
Transmission Line Description 2025 2026 2027 Planned 2028 Planned 2029 5-Year Planned 5-Year
Planned Planned Cost Cost Planned Cost Idaho Planned Cost
Cost Cost Cost Oregon
Line 731—Reconstruct the Reconstruct the $17,979 $3,179 $21,158
BOMT—HBRD 138-kV line BOMT-HBRD 138-kV line
(T708)line to become new (T708)line to become new
double-circuit 230/138-kV double-circuit 230/138-kV
line(T731/T,Idaho line(T731/T482).
Construction will be single-
pole steel structures on
foundations.
Line 920—New line for new 2027 project for Greenleaf $23 $241 $1,423 $1,687
Greenleaf Substation Substation will require
(GNLF),Idaho rebuild of portion of
CDWL—WDJN section of
line 251 to a double-circuit
138/69-kV configuration.
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8.5. Distribution Asset Management and Inspection Initiatives
Idaho Power's distribution asset management programs include condition-based, detailed,
and ground visual inspection; distribution wood pole inspection and treatment; and line
equipment inspections. Line patrol personnel meet on a quarterly basis to review and maintain
alignment on the types of defects they look for as well as the proper priority categorization
placed on defect identification. These exercises help to create and maintain consistency in
inspection and reporting practices among inspectors and across the regions in Idaho Power's
service area.
Annual inspections performed in Oregon Tier 2 and Tier 3 zones comply with the requirements
of Oregon Administrative Rules in Chapter 860, Division 24: frequency of inspections and
identification of defects and potential ignition sources.
Idaho Power implements an enhanced overhead distribution "hardening" program, detailed in
section 8.5.5.
8.5.1. Ground Visual Inspection
Annually, qualified line patrol personnel (trained in distribution line inspection procedures and
experienced in distribution line construction) complete visual wildfire mitigation inspections of
the distribution lines located in Tier 3 zones to identify Priority 1 defects. The ground patrols
are completed using four-wheel-drive vehicles, ATVs, UTVs, or on foot. They involve inspection
at each individual pole and incorporate the use of visual observation, binoculars, and/or UAVs,
as appropriate. These inspections identify potential line defects, which are then documented,
prioritized, and scheduled for repair consistent with defect classification. Detailed distribution
inspections are completed on a predetermined schedule and may be performed in conjunction
with annual visual inspections.
8.5.2. Line Equipment Inspection Program
Line equipment in wildfire risk zones, including capacitor banks, automatic reclosing devices,
and regulators, are inspected annually prior to wildfire season by line operations technicians.
The inspection includes a visual inspection and, when electronic controls are present,
control data is also analyzed.
8.5.3. Thermal Imaging (Infrared) Inspections
Idaho Power annually inspects targeted distribution lines and equipment within Tier 3 zones
using thermal imaging (infrared) cameras. Compromised electrical connections and overloaded
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Idaho Power Company Wildfire Mitigation Plan 2025
equipment may be identified using thermal imagery. Identified risks will be prioritized and
mitigated consistent with defect classification.
8.5.4. Wood Pole Inspection and Treatment Program
On a 10-year inspection cycle, wood poles are visually inspected, sounded, and bored for
defects and decay. The procedure for the Distribution Wood Pole Inspection and Treatment
Program is consistent with and elaborated on earlier in this section under the Transmission
Wood Pole Inspection and Treatment Program.
8.5.5. Overhead Primary Hardening Program
Overhead distribution infrastructure located in Tier 3 zones is analyzed, inspected, and may be
hardened depending on inspection findings, proximity to fuels that may be conductive to
wildfires, and risk model data. The Overhead Primary Hardening Program is intended to
upgrade or repair certain overhead distribution infrastructure to reduce potential risk of
ignition. The following outlines the core strategies Idaho Power utilizes as part of the Overhead
Primary Hardening Program. However, Idaho Power's team is continually researching and
evaluating industry practices and emerging technologies relative to primary hardening.
Notable hardening criteria is expanded on below.
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Idaho Power Overhead Distribution Primary Hardening
Program Strategies*
• Replace"small conductor"with new 4 ACSR or larger conductor.
• Replace or repair damaged conductor.
Wildfire Mitigation Plan 2025 Idaho Power Co—n�:ir
• Re-tension loose conductors including"flying taps"and slack spans as required.
• Replace wood-stubbed poles with new wood poles.
• Replace white and yellow square tagged poles with new wood poles.
• Replace wood crossarms with new fiberglass crossarms.
• Replace steel insulator brackets with new steel pins/fiberglass crossarms.
• Replace wedge deadends on primary taps with new polymer deadend strain insulators.
• Replace aluminum deadend strain insulators with new polymer deadend strain insulators.
• Replace porcelain switches with new polymer switches.
• Install bird/animal guarding.
• Replace hot line clamps:
o Replace aluminum stirrups.
o Install avian cover.
o Relocate arresters.
• Update capacitor banks
o Replace swelling capacitors.
o Replace oil-filled switches with vacuum style.
o Replace porcelain switches with polymer switches.
• Install disconnect switches on CSP transformers.
o Install avian cover.
• Update down guys.
o Replace/Install down-guy insulators with fiberglass insulators.
• Tighten down guys.
o Tighten hardware.
• Correct third-party pole attachment clearances(report to Joint Use department).
• Replace all arresters with non-expulsion arresters.
• Replace all expulsion fuses with ELF or SMU Power fuses.
*Overhead distribution infrastructure located in Tier 3 zones is analyzed,inspected,and hardened as appropriate utilizing the
strategies indicated above depending on inspection findings,proximity to fuels that may be conductive to wildfires,and risk
model data.
Conductor "Small" - •
Idaho Power is implementing replacement of small conductors in Tier 3 zones as part of the
Overhead Primary Hardening Program. Small conductors are those in sizes less than that of
4ACSR conductor. Examples of small wires include 6Cu, 6-3SS, 8A, 8A CW, 91R, etc. These small
conductors are targeted to be replaced with standard larger conductors, primarily with 4ACSR
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Idaho Power Company Wildfire Mitigation Plan 2025
Wood Crossarm Replacement
Wooden crossarms will continue to be replaced with fiberglass crossarms and steel pins as part
of the Overhead Primary Hardening Program. And, whenever work is being completed on a
structure that requires replacement of existing wooden crossarms, Idaho Power may install
fiberglass crossarms.
Porcelain Switch Replacement
Porcelain switches located in Tier 3 zones will continue to be replaced with polymer switches.
Additionally, associated hot clamps and stirrups will be replaced. This work will be coordinated
and included in the overhead primary hardening program.
Fuse Options
Idaho Power replaces expulsion fuses with non-expulsion fuses in Tier 3 zones as a part of its
distribution overhead primary wildfire hardening program.
8.6. Ignition Tracking and Analysis
The WMP is founded on the goal of minimizing the probability that the company's equipment
causes a wildfire. The company has evaluated and implemented mitigation strategies to reduce
the likelihood of ignition and tracks outage events to gauge performance.
The company maintains an Outage Management System (OMS) database for reliability and
performance reporting. This database may be utilized to monitor outage events and evaluate
whether equipment is more susceptible to performance issues or has the potential to act as an
ignition source. Analysis may include factors such as outage location, timing, and wildfire
season, particularly in wildfire risk zones. Environmental factors like vegetation, fuel moisture,
weather, and seasonal conditions may also be considered.
Most outage events do not result in ignitions, and outcomes are often influenced by external
factors beyond the company's control. Outages may be reviewed on a case-by-case basis, and
insights from this process may also be used to inform Idaho Power's asset inspection programs,
helping to identify and prioritize equipment that may require maintenance. If outages are
associated with equipment failure, additional analysis may be conducted to determine whether
equipment issues align with reported ignition events.
The company may also use tools linked to the OMS database to support analysis. For example,
dashboards can provide details on outage events involving primary line fuses, transformer
fuses, and automatic reclosing devices. These tools may help analyze wildfire risk for
distribution circuits, track performance trends, and inform inspection and
maintenance schedules.
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Wildfire Mitigation Plan 2025 Idaho Power Company
Ignition
Idaho Power is making steady progress toward developing an ignition tracking database.
In 2025, workflows • processes will •- completed to begin systematically tracking and
analyzing ignition events related to utility infrastructure, enabling data-driven decisions and
continuous improvementof wildfire • •
Idaho Power plans to begin incorporating information from its ignition tracking processes
into root cause analysis efforts. This integration will allow the company to focus on
enhancing its understanding of the causes of ignition events to implement more measures to
prevent reoccurrence.
8.6.1. Root Cause Analysis
Idaho Power exercises its discretion to conduct investigations and root cause analysis (RCA)
where appropriate for repetitive equipment or material failure, significant incidents, and near
misses. RCA is a systematic process of investigating adverse events and includes gathering
evidence and details of the failure to determine the cause and prevent future occurrences.
8.7. Vegetation Management
8.7.1. Overview
Idaho Power's Transmission and Distribution (T&D) Vegetation Management Program (VMP)
addresses public safety, regulatory compliance, electric reliability, and helps to safeguard T&D
lines from trees and other vegetation that may cause an outage or damage to facilities.
Specifically, the lines are inspected periodically, and trees and vegetation are cleared away
from the line while certain trees are removed entirely. In addition, the VMP addresses the
clearing of vegetation near the base of certain poles and line structures. The responsibilities of
the VMP include the planning, scheduling, and quality control of VMP-associated work.
The VMP is active year-round and complies with applicable NESC, federal, and
state requirements.
Idaho Power faces challenges that can impede its ability to complete all aspects of its
vegetation management goals. These include, but are not limited to, landowners who refuse
pruning or removal of trees, shortage of qualified labor resources in the vegetation line clearing
industry, inclement weather and terrain limiting access to overhead electric facilities during
some seasons, urban growth that increases the number of trees near overhead electric facilities
and cycle-buster trees that grow back after pruning more rapidly than other trees in the
inventory. Given these obstacles, Idaho Power adheres to the vegetation management
program outlined below to the extent practicable.
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Idaho Power Company Wildfire Mitigation Plan 2025
Additional vegetation monitoring tools are in various stages of development, and Idaho Power
will evaluate such tools for potential future implementation.
8.7.2. Program Components
Idaho Power's key components of its VMP, relative to the WMP, are summarized in Table 15.
Table 15
Vegetation Management Program summary
Vegetation Management
Transmission
Pre-Fire Season Inspection and Mitigation
Line Clearing Cycle Goal:3-year cycle for valley areas and 6-year cycle for mountain areas
Tree Removals—Hazard Trees
Targeted Pole Clearing
100%Quality Assurance/Quality Control Auditing in Tier 3 and Tier 2 Zones
Distribution
Pre-Fire Season Inspection and Mitigation
Line Clearing Cycle Goal:3-year cycle in all areas with mid-cycle pruning occurring in second year in
Tier 3 and Tier 2 Zones*
Tree Removals—Cycle Busters/Hazard Trees
Targeted Pole Clearing
100%Quality Assurance/Quality Control Auditing in Tier 3 and Tier 2 Zones
*Distribution line clearing cycles vary by utility.Idaho Power has set a goal of achieving a 3-year cycle of distribution line clearing.
Reliability data has shown that vegetation contact is one of the most likely sources of faults
and possible ignition on the system. As noted in section 4.5.6., customers' electric interruptions
related to vegetation interference reduced significantly in years where enhanced vegetation
management took place compared to years before these activities were performed. As a result,
Idaho Power employs enhanced vegetation management practices in both Tier 2 and Tier 3
zones. These practices include mid-cycle patrols and pruning in the second year of the cycle to
address "cycle buster" trees, along with annual "hotspot" patrols to address any new hazard
trees or unexpected vegetative growth that poses an imminent threat of contact with energized
facilities. In addition, Idaho Power strives to complete audits for all pruning work performed in
Tier 2 and Tier 3 zones. The audits confirm that pruning cuts meet the specification and proper
clearance was obtained. Table 16 summarizes vegetation management activities with respect to
wildfire risk zones.
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Wildfire Mitigation Plan 2025 Idaho Power Company
8.7.3. Vegetation Management Definitions
Applicable Transmission Lines—Each overhead transmission line operated within WMP
Tier 3 zones at 46 kilovolts (W) or higher.
Cycle Buster—Trees that grow at a rapid rate, requiring a more frequent trimming schedule
than the normal trim cycle.
Hazard Tree—Any vegetation issue that poses a threat of causing a line outage but has either a
low or medium risk of failure in the next month. Hazard trees will be further defined as posing
either a medium hazard or low hazard.
High-Priority Tree—Any vegetation condition likely to cause a line outage with a high risk of
failure in the next few days or weeks. High-priority trees could also be vegetation that is in good
condition but has grown so close to the lines that it could be brought into contact with the line
through a combination of conductor sag and/or wind-induced movement in the conductor or
the vegetation.
Line Clearing Cycles—T&D clearing of lines defined on a periodic basis.
Table 16
Summary of vegetation management activities and schedules
Vegetation Management Inspection Interval
Inspections and Activity Idaho Oregon Idaho Oregon Idaho Oregon
Schedule N Zonesk N Zonesk Tier 2 Zone Tier 2 Zone Tier 3 Zone Tier 3 Zone
Transmission
Hazard Tree Patrol on Annually Annually Annually Annually Annually Annually
NERC/WECC Lines
Cycle Patrol/Pruning—
Valley Locations 3 Years 3 Years 3 Years 3 Years 3 Years 3 Years
Cycle Patrol/Pruning—
Mountain Locations 6 Years 6 Years 6 Years 6 Years 6 Years 6 Years
Wildfire Mitigation Patrol/Pruning None None None None Annually Annually
Cycle Buster Patrol/Pruning 18 Months 18 Months 18 Months 18 Months 18 Months 18 Months
(Documented Cycle Buster Trees)
Distribution
Wildfire Mitigation Patrol/Pruning None None Annually Annually Annually Annually
Cycle Patrol/Pruning 3 Years 3 Years 3 Years 3 Years 3 Years 3 Years
Mid-Cycle Patrol/Pruning None None 2 Years after 2 Years after 2 Years after 2 Years after
Cycle Prune Cycle Prune Cycle Prune Cycle Prune
Cycle Buster Patrol/Pruning None 18 Months Covered by Covered by Covered by Covered by
Mid-Cycle Mid-Cycle Mid-Cycle Mid-Cycle
Quality Assurance(Transmission and Distribution)
Post-Pruning Audit Inspections Sampling Sampling 100% 100% 100% 100%
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Idaho Power Company Wildfire Mitigation Plan 2025
8.7.4. Transmission Vegetation Inspection and Management
Maintaining a vegetation-free clearance zone near transmission lines has long been a priority
for Idaho Power. The clearance zone is voltage-level dependent and defined by federal and
state regulations.
8.7.4.1. Transmission Vegetation Inspections
Utility arborists annually conduct aerial and/or ground patrols on each applicable transmission
line to identify and mitigate vegetation hazards. In addition, transmission patrol personnel
inspect all applicable transmission lines once a year to identify any transmission defects and
vegetation hazards. During these inspections, the patrol personnel identify hazardous
vegetation, within or adjacent to the ROW, which could fall in or onto the transmission lines or
associated facilities. The patrol personnel also evaluate the hazardous vegetation based on the
level of potential threat posed, categorizing the vegetation as a higher priority, medium hazard,
or lower hazard. Any hazardous vegetation found is reported to the utility arborist and
documented. Any hazardous vegetation categorized as higher priority and that presents a risk
to cause an outage at any moment is expected to be reported without any intentional time
delay to the grid operator. The utility arborist conducts a follow-up inspection if potential
hazard trees or grow-ins are identified. The utility arborist prioritizes and schedules remedial
action for all reported vegetation issues.
8.7.4.2. Transmission Line Clearing Cycles
Transmission lines are cleared on long-term cycles based on three years for urban and rural
valley areas and six years for mountain areas. However, shorter clearing cycles may occur if
conditions dictate out-of-cycle trimming. In most cases, vegetation is cleared primarily through
manual cutting of targeted trees and tall shrubs. When appropriate, tree-growth regulators
and spot herbicide treatments are applied in compliance with federal or state requirements.
These treatments are effective for reducing re-growth of sprouting deciduous shrubs and trees
and extending maintenance cycles.
Online, cloud-based vegetation management software is utilized to plan tree pruning
and removal work, to assign this work to crews, and to document the dates work is planned,
assigned, completed, and audited.
8.7.4.3. Transmission Line Clearing Quality Control and Assurance
In non-wildfire risk zones, audits are performed on a random sample of pruning
worksites. These audits are performed through a combination of the contracted arborists that
planned the work and Idaho Power's utility arborists. In Tier 2 and Tier 3 zones, audits are
performed on 100% of pruning work regardless of the reason for the patrols and
pruning. The audits are performed by a combination of contracted arborists and Idaho Power's
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Wildfire Mitigation Plan 2025 Idaho Power Company
utility arborists to check whether pruning cuts meet specification and proper clearance was
achieved. This quality control and assurance program has proven valuable. These audits have
discovered trees that were either improperly pruned or not pruned at all. As a result, Idaho
Power requested the pruning contractor re-prune these circuits to achieve satisfactory results.
8.7.5. Distribution Vegetation Management
Idaho Power is actively working to clear distribution lines throughout the company's service
area on a three-year cycle. Additionally, in Tier 2 and Tier 3 zones, Idaho Power completes
annual vegetation line inspections and mid-cycle clearing of the lines in the second year. The
sections below describe Idaho Power's line clearing cycle and inspection processes.
8.7.5.1. Distribution Line Clearing Cycles
Idaho Power is actively working to clear distribution lines on a three-year cycle. In Tier 2 and
Tier 3 zones, Idaho Power's strives to perform mid-cycle pruning in the second year to remove
faster growing vegetation to ensure the lines are clear of vegetation for the full pruning cycle.
In addition, Idaho Power clears lines on an "as-needed basis" in the situations where fast
growing, unexpected growth occurs and is reported by any employee or customer.
8.7.5.2. Distribution Vegetation Inspections
In addition to regular cycle pruning activities, utility arborists are annually conducting ground
patrols to identify potential vegetation hazards of each distribution line in Tier 2 and Tier 3
zones. In addition, distribution patrol personnel also inspect the lines in the Tier 3 zones
annually. During these inspections, patrol personnel identify infrastructure defects and
hazardous vegetation, within or adjacent to the ROWS, that could fall onto the distribution lines
or associated facilities. The patrol personnel then evaluate the level of threat posed by the
hazardous vegetation by categorizing the vegetation as a higher priority, medium hazard,
or lower hazard. Any hazardous vegetation found is reported to the utility arborist and
documented. Any hazardous vegetation categorized as a higher priority that presents a risk to
cause an outage at any moment is expected also be reported to the grid operator without any
intentional time delay. The utility arborist conducts a follow-up inspection if potential hazard
trees or grow-ins are identified. The utility arborist prioritizes and schedules any remedial
action for all reported vegetation issues.
Online, cloud-based vegetation management software is utilized to plan tree pruning and
removal work, to assign this work to crews, and to document the dates work is planned,
assigned, completed, and audited.
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Idaho Power Company Wildfire Mitigation Plan 2025
8.7.5.3. Distribution Line Clearing Procedures
In most cases, vegetation is cleared as scheduled work and includes, but is not limited to,
the removal of dead branches overhanging power lines, weak branch attachments,
damaged root base, or dead or dying trees leaning toward Idaho Power facilities.
Vegetation clearing methods include crews using chain saws or specialized pruning machines.
Trees are cleared using a pruning procedure called directional or natural pruning, a method
recommended by the International Society of Arboriculture, and the ANSI A300 standards.
When appropriate, tree-growth regulators and spot herbicide treatments are applied in
compliance with federal or state requirements. These treatments are effective for reducing
re-growth of sprouting deciduous shrubs and trees and extending maintenance cycles.
Through its VMP, Idaho Power has a target to maintain clearance distance between vegetation
and conductors as follows:
• Five feet for conductors energized at 600 through 50,000 volts.
• Clearances may be reduced to three feet if the vegetation is not considered to be readily
climbable because the lowest branch is greater than eight feet above ground level.
• New tree growth no larger than % inch in diameter may intrude into this minimum
clearance area provided it does not come closer than six inches to the conductor.
This new growth is identified during line patrols and removed.
• For conductors energized below 600 volts, vegetation is pruned to prevent the
vegetation from causing unreasonable strain on electric conductors.
8.7.5.4. Distribution Line Clearing Quality Control and Assurance
Similar to Idaho Power's vegetation audit process for transmission, in non-wildfire risk zones,
audits are performed on a random sample of pruning worksites. Audits are performed through
a combination of contracted arborists and Idaho Power's utility arborists. In Tier 2 and Tier 3
zones, audits are performed on all pruning work. If an audit indicates unsatisfactory results,
such as improper pruning, Idaho Power requests the pruning contractor re-prune circuits to
achieve satisfactory results.
8.7.6. Pole Clearing of Vegetation
Idaho Power has historically cleared vegetation from the base of certain transmission wood
poles and a limited number of distribution wood poles in Idaho. These vegetation clearing
practices are an effective method of minimizing wildfire damage to existing wood poles.
Where acceptable and permissible, Idaho Power removes or clears vegetation in a 20-foot
radius surrounding wood poles and applies a 10-year weed-control herbicide that remains
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Wildfire Mitigation Plan 2025 Idaho Power Company
effective for several years (SpraKil SK-26 Granular). In 2023, Idaho Power submitted an SF-299
application with the Oregon Bureau of Land Management (BLM) Vale District Office to prepare
an environmental assessment to use the same ground sterilant on transmission and distribution
facilities in Oregon. This application is still being reviewed by the BLM.
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Idaho Power Company Wildfire Mitigation Plan 2025
9. Wildfire Response
9.1. Overview
Idaho Power responds to wildfires involving or impacting its facilities and/or resulting in a
system outage. Depending on the specific circumstances, Idaho Power may also respond to
wildfires with the potential to result in an outage. Idaho Power's response includes the
following without limitation. These actions are taken on a 24-hour basis:
• Taking appropriate steps, where safe to do so, to protect Idaho Power-owned facilities
from fire damage. This may include emergency de-energization for any of the reasons
described below.
• Restoring electrical service following an outages; and,
• Communicating with and informing customers.
9.2 Emergency De-energization
With exposure to environmental conditions, overhead transmission and distribution lines are
subject to a variety of effects that may influence reliability and overall performance. When a
wildfire is near or approaching, Idaho Power may conduct an emergency de-energization of
overhead lines for the following reasons:
• To ensure the safety of firefighters and firefighting activities, such as aircraft dropping
fire retardant or water on or near overhead lines;
• To avoid arcing or the conduction of electricity through the air when wildfires and/or
concentrated smoke is in vicinity;
• To prevent a wildfire from burning through an energized line that may be at risk of fire
damage or arcing.
9.3 Response to Active Wildfires
Idaho Power field crews are trained to respond to active wildfires to monitor the situation
regarding Idaho Power's facilities. Although they carry certain fire suppression equipment for
use on very small fires in limited situations, Idaho Power's crews are not professionally trained
firefighters and are instructed not to place themselves in a hazardous position when responding
to wildfires. When responding to an active wildfire, Idaho Power personnel immediately report
to, and take appropriate direction from, the Incident Commander (IC) or other fire response
entity official with jurisdiction over the incident.
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Wildfire Mitigation Plan 2025 Idaho Power Company
In 2024, Idaho Power began using a dedicated wildland fire engine and firefighting personnel in
certain situations to support on-the-ground safety and infrastructure protection. Idaho Power
intends to continue to utilize contracted firefighting personnel in 2025 on an as-needed,
case-by-case basis. The personnel protect critical infrastructure and provide situational
awareness and coordination within the incident command structure during an event and
safeguard utility crews working on restoration activities.
9.4. Restoration of Electrical Service
Idaho Power personnel restore electrical service when it is safe to do so following a wildfire.
At certain times, emergency or unplanned de-energization of lines requires qualified line
personnel to conduct "emergency" patrols (inspections) of the de-energized lines. These patrols
identify outage causes, damaged facilities, ingress/egress routes, and restoration requirements
(number of crews, crew sizes, and necessary materials).
If damage is detected, trained field crews report to the site where damage has occurred with
equipment and new materials and develop a plan to remove and rebuild damaged facilities.
Depending on the situation, contracted field crews—such as line crews and vegetation
management crews—are also deployed to assist in restoration efforts. Restoration work may
take hours or, in some cases, days to complete. Depending on the extent of damage,
customers may need to perform repairs on their facilities and pass inspections by local agencies
prior to having full electric service restored.
9.4.1. Mutual Assistance
Idaho Power is a member of the Western Region Mutual Assistance Group (WRMAG), of which
most western United States electric utilities are also members. Member utilities provide
emergency repair and restoration assistance to other member utilities requesting assistance
when dealing with damaged electric facilities following a significant wildfire or weather event.
In the event of a wildfire that causes widespread damage to Idaho Power's system, Idaho
Power may request restoration assistance via the WRMAG as a last resort option after utilizing
available internal personnel and contracted entities.
9.5. Public Outreach and Communications
Idaho Power follows its relevant internal processes to guide wildfire-related communication
protocols. External communication includes customers, public safety partners, and operators of
critical facilities.
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Idaho Power Company Wildfire Mitigation Plan 2025
10. Communicating About Wildfire
10.1. Objective
Idaho Power communicates information about this Wildfire Mitigation Plan (WMP) — including
public safety power shutoff(PSPS) and wildfire issues in general — to employees, customers,
government officials, the public, and other stakeholders. The following objectives guide all
wildfire-related communications:
• Educate customers about how to prepare for wildfire-related outages, including where
to find outage and PSPS information, and how to update contact information.
• Explain how customers can reduce wildfire risk.
• Raise awareness about Idaho Power's work to protect the grid from wildfire and reduce
wildfire risk.
10.2. Community Engagement
Idaho Power presents and distributes information on its WMP to a wide variety of stakeholders
including public safety partners, critical facilities, and the community.
Each year, prior to wildfire season, communications begin with public safety partners,
including the Idaho and Oregon state offices of emergency management, county emergency
managers, local governments, and social service and welfare agencies. These communications
are held both individually and in larger groups during Local Emergency Planning Committee
meetings, where the company provides an overview of the WMP and discusses the PSPS plan
and outage preparation. Feedback from these partners is captured each year to inform future
versions of the WMP, along with collaboration to identify opportunities for public outreach.
Idaho Power additionally focuses engagement efforts with operators of critical facilities.
These operators include, but are not limited to, hospitals, police and fire stations,
wastewater treatment facilities, and telecommunication providers. During these interactions,
Idaho Power ensures contact information and communication preferences are current,
provides an overview of the communication process during a PSPS, and shares outage
preparedness tips.
Public meetings are held through various formats, including formal presentations, open-house
events, community-based organization collaborations, and virtual town halls throughout the
company's service area. Topics include review of the WMP, communication during a PSPS,
wildfire prevention, and emergency outage preparedness.
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Wildfire Mitigation Plan 2025 Idaho Power Company
Additionally, to ensure messaging reaches access and functional needs customers, the company
collaborates with the Living Independent Network Corporation, the Southwest Idaho Area
Agency on Aging, and Norco to present on outage preparedness. The information provided
includes considerations for older adults and individuals with disabilities, and information about
medical equipment considerations during an outage, emphasizing the importance of
battery backups.
Idaho Power's 2024 targeted outreach efforts included customers more likely to experience a
PSPS due to proximity to or within a wildfire risk zone. Attendance at outreach engagements
significantly varied, with some meetings having no participants and others attracting many
attendees reaching levels near 100. The company's 2024 outreach efforts are summarized in
Table 17.
Table 17
Idaho Power community engagement, 2024
Type Details Date Type Details Date
Public Meetings Boise,ID—BSU Hazard and Feb.1 Public Meetings Emmett,ID—Community May 17
Resilience Institute
Public Safety Partners ID Military Division—FEMA Feb.13 Public Meetings Ola,ID,High Valley— May 20
West Collective Cohort Community
Training
Public Safety Partners Baker County,OR— Feb.27 Public Meetings Bannock County,ID, May 20
Emergency Management Northern Pocatello—
Coordinator Community
Public Safety Partners ID—Living Independent Feb.29 Public Meetings Bannock County,ID, May 21
Network Southern Pocatello—
Community
Public Safety Partners Halfway,OR—Outage March 4 Public Meetings Oneida County,ID— May 21
Preparedness Fair Community
Public Safety Partners Canyon County,ID— March 4 Public Meetings Horseshoe Bend,ID— May 21
Emergency Management Community
Coordinator
Public Safety Partners Power County,ID—Local March 7 Public Meetings Homedale,ID,Adrian, May 22
Emergency Planning OR—Community
Committee
Public Safety Partners Lemhi County,ID— March 11 Public Meetings Eagle,ID—Community May 22
Emergency Management
Coordinator
Public Safety Partners Ada County,ID—Local March 14 Public Meetings Twin Falls County,ID,Rock May 22
Emergency Planning Creek—Community
Committee
Public Safety Partners Bannock County,ID— Mar 15 Public Meetings Unity,OR—Community May 23
Emergency Management
Coordinator
Public Safety Partners Ontario,OR—Chamber of March 18 Public Meetings Mountain Home,ID— May 23
Commerce Community
Public Safety Partners Elmore County,ID— March 18 Public Safety Partners Elmore County,ID—Local May 23
Emergency Management Emergency Planning
Coordinator Committee
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Idaho Power Company Wildfire Mitigation Plan 2025
Type Details Date Type Details Date
Public Safety Partners Gem County,ID—Local March 19 Public Meetings Weiser,ID—Community May 28
Emergency Planning
Committee
Public Safety Partners Payette County,ID— March 20 Public Safety Partners Boise,ID—Mayor's Office May 29
Emergency Management
Coordinator
Public Safety Partners Owyhee County,ID— March 20 Public Meetings Halfway,OR—Community May 29
Emergency Management
Coordinator
Public Safety Partners Adams County.ID * Public Meetings Cambridge,ID— May 30
Community
Public Safety Partners Washington County,ID * Public Meetings New Meadows,ID— June 3
Community
Public Safety Partners Valley County,ID— March 28 Public Meetings Power County,ID— June 3
Emergency Management Community
Coordinator
Public Safety Partners Power County,ID—Local March 28 Public Meetings Yellow Pine,ID— June 4
Emergency Planning Community
Committee
Public Safety Partners Ada County,ID— April 3 Public Meetings Virtual Offering—All June 4,5,
Dispatch/Fire Chiefs Customers 6
Public Safety Partners Blaine County,ID— April 4 Public Meetings Valley County,ID— June 4
Emergency Management Community
Coordinator
Public Safety Partners Oneida County,ID— April 4 Public Meetings Cascade,ID—Community June 4
Emergency Management
Coordinator
Public Safety Partners Idaho County,ID— April 8 Public Meetings Star,ID—Community June 4
Emergency Management
Coordinator
Public Safety Partners Bannock County,ID—Local April 8 Public Meetings Elmore County,ID,Boise June 4
Emergency Planning River Senior Center—
Committee Community
Public Safety Partners Twin Falls County,ID— April 9 Public Meetings McCall,ID—Community June 5
Local Emergency Planning
Committee
Public Safety Partners Power County,ID—Local April 25 Public Meetings Idaho County,ID— June 5
Emergency Planning Community
Committee
Public Safety Partners Boise County,ID— April 29 Public Meetings Donnelly,ID—Community June 7
Emergency Response,Boise
National Fire Leadership,
Idaho Department of Lands
Leadership
Public Meetings Canyon County,ID— April 30 Public Meetings Council,ID—Community June 7
Community
Public Safety Partners Boise County,ID— April 30 Public Meetings Boise,ID,City Council— June 10
Emergency Management Community
Coordinator
Public Meetings Murphy,ID—Community May 1 Public Safety Partners Idaho Department of June 13
Health and Welfare
Public Meetings Idaho City,ID—Community May 1 Public Meetings Kuna,ID—Community June 13
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Wildfire Mitigation Plan 2025 Idaho Power Company
Type Details Date Type Details Date
Public Meetings Vale,OR—Community May 2 Public Meetings Blaine County,ID,Halley— June 18
Community
Public Meetings Boise,ID—Firewise Wildfire May4 Public Meetings Blaine County,ID, June 19
Preparedness Day Ketchum—Community
Public Safety Partners Ada County,ID—Emergency May 7 Public Meetings Payette County,ID— June 24
Management Coordinator Community
Public Safety Partners Blaine County,ID—Local May 9 Public Safety Partners Boise,ID—Ada County June 24
Emergency Planning Emergency Management
Committee Executive Council
Public Meetings Crouch,Garden Valley,ID— May 13 Public Meetings New Plymouth,ID— June 25
Community Community
Public Meetings Lemhi County,ID,Salmon May 13 Public Meetings Juntura,OR—Community June 26
Region—Community
Public Meetings Lemhi County,ID,Elk Bend May 13 Public Meetings Boise,ID,Micron June 26
Region—Community Environmental Health&
Safety Fair—Community
Public Meetings Lowman,ID—Community May 14 Public Meetings Boise,ID,Avimor— June 27
Community
Public Meetings Lemhi County,ID, May 14 Public Meetings Living Independent June 27
Leadore—Community Network,Norco,
Southwest Idaho Area
Agency on Aging—Virtual
Offering
Public Meetings Lemhi County,ID,North May 14 Public Meetings Placerville,ID— July 6
Fork—Community Community
Public Meetings Malheur County,OR— May 15 Public Safety Partners Boise,ID,Ada County July 8
Community Extreme Heat Emergency
Operations Coordination
Public Meetings Nyssa,OR—Community May 16 Public Safety Partners Boise,ID—Ada County July 24
Severe Storm System
Public Safety Partners Boise,ID—Idaho Aug.24
Department of Corrections
*Attempts to hold the indicated meeting type were unsuccessful.
As the company prepares for the 2025 wildfire season, efforts will continue to provide
community and customer outage preparation education with a minimum of one public meeting
in each county with a wildfire risk zone.
10.3 Community Resource Centers
Each county in Idaho Power's service area has unique needs during outage events and requires
a customized, flexible approach. During annual meetings with county emergency managers,
Idaho Power refines county-specific strategies in preparation for potential large-scale,
extended outages. These strategies include working with emergency managers to identify
Community Resource Center (CRC) locations to be used, if appropriate, in a PSPS event.
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Idaho Power Company Wildfire Mitigation Plan 2025
If a PSPS event is forecasted, Idaho Power strives to work directly with local public safety
partners to identify and meet the needs of the local community. Services provided in
collaboration with emergency managers could include, as appropriate:
• Stand-up of CRC
• CRC location(s) and logistics included in community outreach/outage notifications
• CRC resources
• Food, water, and other basic needs
• Charging stations
• Auxiliary service coordination, such as medical services, housing assistance,
family reunification, etc.
• Mobile generators and/or battery packs to serve essential community resources
10.4. Customer Communications
Idaho Power's dedication to safety guides our strategy for wildfire-related communication to
our customers. Communication methods and timing vary based on the audience we are trying
to reach and the goal of the communication.
Idaho Power's goal in 2024 was to provide outreach and communications on our wildfire
mitigation efforts for all customers, with focused awareness on the PSPS program for
customers living in or near a wildfire risk zone who could potentially be impacted by a PSPS
event. To achieve this goal, Idaho Power broke its approach into two categories:
1. Broad outreach to all customers.
2. Additional outreach to customers in areas where PSPS events are more likely.
The company uses a variety of outreach methods, described below, to reach a broad customer
base with messages about wildfire safety, summer outage preparedness, and grid hardening
efforts. Outreach to customers in areas more likely to have a PSPS in 2024 was focused on
urging customers to update or confirm accurate contact information and how to find
community-specific information related to PSPS and wildfire mitigation work.
10.4.1. Key Communication Methods
Idaho Power communicates with customers and the public before and throughout wildfire
season to inform them of steps the company is taking to reduce wildfire risk and ways they can
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Wildfire Mitigation Plan 2025 Idaho Power Company
help prevent wildfires and prepare for outages. Various communication mediums used to
accomplish this include:
• Connections (monthly newsletter sent by Idaho Power to customers.) (Figure 25).
• Videos on topics like vegetation management and PSPS (Figure 26).
• Email messages telling customers how to prepare for wildfires, encouraging them to
update their contact information, and providing information about grid hardening
efforts (Figure 27).
• In 2024, the company notified all customers in PSPS zones by text message or phone call
and postcard (Figure 28) with additional information about PSPS and how to prepare.
This was the first year Idaho Power deployed a targeted PSPS messaging effort at this
scale. Moving forward, Idaho Power plans to continue to work with public safety
partners to determine community-specific needs for messaging as well as internally
evaluate the benefit of targeted messaging vs. more general customer-wide
communication approach.
• News media (news releases, appearances on broadcast TV and radio shows,
interviews, etc.).
• Social media (posts on Facebook, Instagram, and X are an efficient way to reach large
numbers of customers and the public quickly). Social media continues to be a critical
tool for engaging with customers and communicating wildfire safety (Figure 29).
The company's social media campaign for wildfire season focuses on three main
themes:
• Wildfire prevention: What Idaho Power is doing and what customers can do to
reduce wildfire risk.
• Outage preparation: How customers—especially those who live or have businesses
in wildfire risk zones—should prepare for wildfire-related outages.
• Grid maintenance: How Idaho Power protects the grid, keeping energy safe,
reliable, and affordable, even during wildfire season.
• Postcards (Figure 30).
• Bill insert (Figure 31)
• Idaho Power's website (wildfire safety information, such as videos, safety tips, and the
latest version of the WMP) can be found at www.idahopower.com/wildfire. As shown in
Figure 32 on this webpage, the company introduces wildfire and its relationship to
delivering power, information on PSPS, and the following links:
Page 118

Idaho Power Company Wildfire Mitigation Plan 2025
• What is a PSPS?: Explanation of PSPS events, including a map customers can use to
determine if their homes or businesses are in a PSPS zone.
• Be Prepared for Wildfire Season: Preparation tips like building an outage kit and
making a plan for feeding livestock, etc.
• Protecting the Grid: Idaho Power measures to enhance grid resiliency and reduce
wildfire risk; an interactive map showing Tier 3 and Tier 2 zones and a link to
the WMP.
• How You Can Reduce Wildfire Risk: Tips for preventing wildfires when camping,
using fireworks, hauling trailers, etc.
• PSPS Event Information: Real-time information on active PSPS events,
estimated shutoff time, outage duration, and customers impacted.
• Paid advertising (radio, digital [Figure 33] , and print advertisements).
• Flyers (Figure 34).
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kegsrem and inlet m Wt deW¢Wwanq m the wnntl will rya ^�d hre.BN f weather From the Electric Kitchen
dano erne OregoM1•Baia tern Aabwn, mM'rtionswartanl a PSPS for saktY Dessert
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eapmdee—fat oR redacts Mdfire prepare br mnlrcal needs.­dupdate d cups hnh zvawuerties.daed
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for at least bur Murs 1prefnagY orerM¢b.Umwm aM gamisn vets z&ed almeMa " _.
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Figure 25
May 2024 issue of Connections
Page 119

Wildfire Mitigation Plan 2025 Idaho Power Company
What is a PSPS? Share
PSPS Notifications
PSPS Watch PSPS Worwig FISPS Wage Alen PSPS Updates PSPS Nat
0 o"Ao *',i%, *Men
MORE'ADEOS
0• . Youbbe
Figure 26
Idaho Power developed an educational video on PSPS events.
Page 120

Idaho Power Company Wildfire Mitigation Plan 2025
i
Join Our Virtual Meetings on Wildfire and PSPS
Idaho Power will host three virtual meetings in early June to explain the
company's wildfire mitigation efforts and how customers can be
prepared for outages. including a Public Safety Power Shutoff(PSPS).
A PSPS is when an electrical company proactively cuts power to an
area where wildfire risk is high due to extreme weather. It is a last resort
for the safety of our customers, employees, and communities.
Interested customers can join any of the following virtual meetings:
Date: June 4 Time: 6-7 p.m.
Date: June 5 Time: 6-7 p.m.
Date: June 6 Time: 6-7 p.m.
For meeting links and more information on Idaho Power's PSPS plan,
our work to protect the grid and reduce wildfire risk, and tips for
preparing for wildfire season, visit idahopower.comlwildfire.
Figure 27
Customer email, May 2024
Page121

Wildfire Mitigation Plan 2025 Idaho Power Company
Public SafetyPower
Our . .s show your property
a wildfire risk zone and could . impacted in the event of a
-
should .
prepared
customers living in or near higher wildfire risk areas are more Come Learn More at One of
Publiclikely to experience a PSPS. These
Date/Time: May 20,2024/6:30 p.m.
What is a PSPS? Location: Hawthorne Middle School
A PSPS is when an electric company like Idaho Hqh rmpercNrc 1025 W Eldredge Road Pocatello,ID 83201
Power proactively turns off the power to an Date/Time: May 21,2024/6:30 p.m.
area where wildfire risk is high due to extreme ® Location: Century High School
weather conditions. 7801 W Diamond Back Dr.Pocatello,ID 83204
A PSPS is a last resort.We work year-round to Lm Humidity
protect the grid and avoid wildfires. However, Date/Time:June 6,2024/6:30 p.m.
if weather conditions lead to extreme fire risk, Location: Oneida County Fire Department
we might need to call a PSPS. High Yhdi 90 S 100 W,Malad City,ID 83252
If a PSPS is necessary,we will provide as much
notification as possible. Please update your contact
information at idahopower.com/contactupdate to
ensure we can reach you in an emergency. D,V�prat
020241daho Power
Figure 28
Postcard to customer living in a WRZ
Page 122

Idaho Power Company Wildfire Mitigation Plan 2025
`0 Idaho Power ...
F„r:n F, /\ Idaho Power ...
• 0 r.:b ished by Lex Freemar
The heat is finally here,and with it.wildfire season For the safety of June 18-Q
our communities.we're increasing the sensitivity settings of powedines Thanks to Idaho News 6 for covering our recent Kuna community
in wildfire-prone areas.These lines will not try to a=maocally re- meeting and to all our customers near wildfire risk zones who have
energize if something causes an outage.This change helps reduce the
risk of sparks causing a fire in dry,hot weather.While this could lead to come out to learn about the wildfire mitigation work we do,including
more frequent outages for some customers,it s an important our public safety power shutoff(PSPS)plan.
temporary measure to reduce wildfire risk during the peak of wildfire If you're interested in leaming more or viewing a recording of our
season_
virtual meeting check out idahopoweccom/psps.
To learn more about our wildfire mitigation efforts.visa
idahopower.comi wildfire.
Idaho News 6•
u^e 1 j Q
• • •, ICYMI: Idaho Power held a public meeting Thursday to discuss
• • their Public Safety Power Shutoff program.A PSPS event means
that Idaho Power could cut power to...See more
Prmenhv drdms out—tirelly 1
I,rn orll l•.!.q..p I
q.auM a alc,rwY rnM. _ -
f
n.1e..n�eroq rM.» k vITv.Cohi
Idaho Power .. ...
Published by Lex Freeman � Idaho Power
• ` Published by Sprout Social
May 3 Q
Tomorrow is Wildfire Community Preparedness Day.Every summer, September 19 Q
wildfires are a threat to our homes,businesses,farms,and forests.They Building and maintaining a safe,resilient grid is Idaho Power's first step
can also cause power outages.Here are some ways to keep you and in reducing wildfire risk.Over the last two years,we've installed more
your family from getting caught off-guard in a summer outage, than 1,500 spark-prevention units and replaced the same number of
regardless of the cause. expulsion fuses,which keep hot particles from hitting the ground.
Plan for needs like refrigerated medicine or powered medical
equipment For more information on steps Idaho Power takes to protect the grid
and reduce wildfire risk visit idahopower.com/wildfire.
�/Find a way to water livestock in case pumps lose power
f Update your contact information:idahopower.com/contactupdate h
Fire season
K �l
• •
K
Wildfires can cause power outages.
Nuke sure you prepare. ,
Figure 29
Example social media posts
Page 123

Wildfire Mitigation Plan 2025 Idaho Power Company
Sorry ' • •
Our records show you live or own property in an area with �P�R
higher than normal wildfire risk-It appears the phone
nwmlxet or email address we have for your account is out
of date eu Na 70
Mwt n0lt70t.0m
Public Safety Power Shutoffs iPSPS)are more likely in your
area than others.It's important that we can reach you in
case of an emergency,like an unplanned outage.Please
take a minute to update you contact information at
idahopowercomrcontactupdate or call us
at 208.398-2323
Thank you for making sure
lNP can stay in touch!
�f
Figure 30
Postcard to customer Idaho Power could not reach with contact information on file
Page 124

Idaho Power Company Wildfire Mitigation Plan 2025
Wil d f ire
season is here.
Make sure
you're ready&
Public Safety Power Shutoff
Every year, wildfires threaten our communities.
To help prevent wildfires, Idaho Power might
need to turn off power to an area where
wildfire risk is high due to extreme weather.
This is called a Public Safety Power Shutoff
(PSPS). A PSPS is a last resort to keep our
communities safe and help prevent wildfire.
Guarding the Grid
Idaho Power works year-round to protect the
grid and prevent wildfires. We build equipment
that meets or exceeds industry standards.
We install spark prevention units,trim trees
away from power lines, and use cutting-edge
technology like infrared imaging to monitor
equipment for defects.
In some areas, we set lines to automatically trip
if trees or debris touch them, reducing the risk
of sparks. In hot, dry, or windy weather, we
might turn off equipment that automatically
re-energizes lines. While these measures can
reduce wildfire risk, they also might increase
the frequency and length of outages.
Learn morp at idahopower.com/psps.
Figure 31
July bill insert
Page125

Wildfire Mitigation Plan 2025 Idaho Power Company
HIDAM
Search IdahoPowercc- Q Contact Us 6 Sign In
SafetyNNW
Mdfire
-lone Cv;ag--Safety.'N ki re Safety
o,rages Every summer, _';____ ,,.._.,names,farms.busnesses.and forests.They can also cause
sa:er�l•f—a-�o� power outages.'re�'----=_ .:-_es,Idaho Power might proactvely shut off power as a'as
wildfire safety resort In some areas:o<ccp cur custcmers employees equ'pment and the pubfc safe.71wsc= ij
Ns is a Public safety 0— called Publ'c Safety Power Shutoffs(PSPS).could last several hours or even days,so ma,e s- _ _-
Shwtcff" prepared.
PSPS E.ent Irfama[im
Be Prepared for w,Id'%season
Protecting:he Grid Outage
How You Can seduce wildfire ^PSPS'S the final step in Idaho Powers precentor efforts.It s a last resort.But wildfires can cause Recommendations for
Pic outages outside of a PSPS event.Lean more below about PSPS evens,hov you can be prepared for Vulnerable Customers
summer outages,and what vm can all do to prevent them. Re,P.
7o leam more about Idaho Pourers PSPS plan.watch our virtual preser aton from June 6,2=41
for _ —aole cC: 5,
- - SU,ri.-trosereq- g
refrigerated medication or
life support systems.
Learn more acw:publ c Fno>v rpr.:o preparefor zr v prc:ect
safety power shutoffs outages and where to go our equipment from
including a map of to stay informed. widfire and prevent
potential PSPS area and outages.Read abo our ut
how you can be prepared. wildfire Mitigaron Plan
here.
Lean more O Lean more O '_earn more O
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Figure 32
Idaho Power's wildfire safety landing webpage

Idaho Power Company Wildfire Mitigation Plan 2025
IV
E WILDFI E
EADY
Update your contact
information case
of outages.
CONTACT INFO
I
Figure 33
Idaho Power digital ad, summer 2024
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Wildfire Mitigation Plan 2025 Idaho Power Company
• • POVM.
All cost mers should be prepared for outages,including a
PSPS?
Map of red and yellow Zldflre risk zones
A public safety power shutoff,or PSPS,is when an electrical utility like �•
Idaho Power proactively turns off power to an area where wildfire risk is m
Ii high due to extreme weather conditions.The outage is an effort to keep I.
.{ our customers,communities,employees,and equipment safe. ,. .
When is a PSPS used?
A PSPS is a last resort to prevent wildfires.From ttlmming trees[o wrapping
poses in fire-resistant mesh to maintaining and impxting our equipment,
wildfire mitigation Is part of year-round,everyday operations at Idaho
Pourer.However,if high winds,dry vegetation,or other weather conditions
lead to extreme fire risk Idaho Power might need to call a PSPS. ICY 'fi
The decision to call a PSPS is based w forecasts and on-the-ground •-^'�' r
observations of many factors,including: .• ,. �" / r
w.�rnw�aon lue Wmaary IM VaM GY Ynlwcm NIa LMry
How will customers be notified?
Idaho Power will provide as much advance notice as reasonably possible to For more information on wildfire risk zones,
help you prepare for a PSPS event.As much as we can,we'll keep you informed visit ..
throughout an event using teat messages,phone calls,and emails.
Make sure to update your contact information at
We'll try to follow this schedule as closely as events allow:
.s.s Where can customers find out more?
Idsnao �� nn Fa... � Visit b to learn more about:
M •Planning fora possible PSPS
•Preparing for summer outages
1 {P t I s Q •Idaho Power's wildfire mitigation measures
�•
•What you can do to help
,,, ia; ,,,,,,•eve, ,,,ee,v,,, „' °,,;' �,,,, In the event of a PSPS,you'll find the latest
�•'4i.'� information at
Figure 34
Idaho Power PSPS flyer
10.4.2. Timing of Outreach
Wildfire-related outreach occurs primarily before and during wildfire season. The timing of
preseason wildfire outreach timing depends on weather conditions. Holding key
communications until wildfire is more prominently on people's minds helps increase the
likelihood people will hear and retain the messages. Early communications encourage
customers to think about wildfire season, how they could prepare for it, their role in preventing
wildfires, and steps Idaho Power is taking to keep the grid safe and reduce wildfire risk.
When the potential for wildfire increases, communications shift in tone. Messaging puts more
emphasis on asking customers to update their contact information, prepare for wildfire,
and help prevent wildfires while recreating.
10.4.3. Communication Metrics
Idaho Power monitors communication activities and uses metrics to evaluate the effectiveness
of our outreach efforts and adjust them as needed.
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Idaho Power Company Wildfire Mitigation Plan 2025
Table 18 summarizes key metrics from Idaho Power's 2024 communication campaign. Idaho
Power will continue looking at metrics that help us improve our communications.
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Wildfire Mitigation Plan 2025 Idaho Power Company
Table 18
Key communication metrics
Metric Definition Success Criteria Reason for Metric Results/Discussion Considerations for Future
Digital Display Ads—Outage Preparation(May—June)and Wildfire Prevention(July—Sept.)
Click-through Rate Number of people Industry average Identifies how well These ads on regional website resulted in The click-through rate was much higher in July(0.13%),
who clicked/total customers engage with 2,727 total clicks in Idaho and Oregon to suggesting that focusing the messaging during the hot
number served the messaging our wildfire landing webpage and a click- portion of pre-fire season might be beneficial.Recommend
ad,expressed as a through rate of 0.09%,surpassing the looking into responsive display ads—could expand the
percentage. click-through rate benchmark of 0.05%. range of placements,increase overall reach,and provide a
Well above industry average. more organic appearance,further boosting the click-
Impressions Number of times an Growth in Helps gauge total reach These ads on regional websites resulted through rate.
ad has been served. impressions in 2.9 million impressions.
Radio—Wildfire Preparedness(May—June)and Prevention(July—Sept.)
Number of Spots Total number of Count increasing/ Identifies number of Wildfire-safety radio ad campaign ran Consider keeping a radio presence but focusing more of the
spots run,including leveraging customers exposed to in Idaho Falls,Twin Falls,and Boise budget on digital tactics that can reach more people.
add-on public safety additional free messaging markets.The Boise market includes
announcements spots as PSAs eastern Oregon,reaching to Baker City.
(PSA) Campaign included a total of 4,265 paid
and PSA match spots-1,204 were in
Spanish and played on Spanish
language stations.
Streaming Audio—Wildfire Preparedness(May—June)and Prevention(July—Sept.)
Impressions Number of times an Growth in Helps gauge total reach English and Spanish ads ran on services Consider shifting some of the traditional radio budget here,
ad has been served. impressions such as Pandora,Amazon Podcast where we're seeing lots of reach.
Marketplace,and Spotify,resulting in
349,292 impressions.
Listen-through Percentage of ad Industry average Identifies how well Listen-through rate of 99.03%for English
Rate plays listened to in customers engage with ads and 97.50%for Spanish.Well above
their entirety messaging the industry average.
Customer Email—Wildfire Season Preparedness(May 2024)
Number Sent Total number of Customer Identifies number of Delivered to 334,449 customers. We send this email in May,at the beginning of fire season
emails sent feedback/count customers receiving the and Wildfire Preparedness Month.We included other
increasing as we message on widely outage preparedness messaging in additional emails.
have more email preferred channel Consider another focused email in July,when the audience
addresses seems most engaged with this message.
Open Rate Percentage of Industry average Identifies how well Open rate of over 50.4%—well above
recipients who customers engage with industry average.
opened the email messaging
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Idaho Power Company Wildfire Mitigation Plan 2025
10.4.4. Customer Feedback
In November 2024, Idaho Power sent a customer survey to its Empowered Community seeking
feedback on attitudes about utilities and wildfire, including perceptions of risk and support for
mitigation measures. We compared this survey to the October 2023 survey, which the company
used to establish a baseline for the effectiveness of our wildfire communication. These surveys
help inform outreach efforts in subsequent years. The following are high-level takeaways from
the survey:
• 78% would support the use of PSPS in extreme weather conditions to reduce the risk
of wildfire (up from 71%in 2023).
• 63% recalled hearing or receiving information about PSPS from Idaho Power or
through the media (up from 9%in 2023).
• 43% recalled getting information about how Idaho Power is working to reduce wildfire
risk (up from 27%in 2023).
• 61% recalled receiving information about how to prepare for outages (up from 34%
in 2023).
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2024 WMP Communication Recap
Idaho Power used many tactics in 2024 to inform customers about the company's WMP,
efforts to protect the grid from wildfire, how customers can reduce wildfire risk, how to
prepare for wildfire-related outages, and PSPS. Outlets included:
• Newspapers—print ads and news coverage
• Radio—paid ads in English and Spanish and news coverage; wildfire-themed
interviews on Spanish-language shows
• TV news coverage
• Printed flyers
• Social media
• Bill inserts
• Digital display ads
• Postcards—Used to inform customers of the PSPS program and invitations for
public meetings
• Spotify—paid ads
• News releases—Includes news releases with other Oregon utilities
• Customer emails
• Customer newsletters
• Text messages—customers in wildfire risk zones
• Phone calls—customers in PSPS zones
• Emails—customers in PSPS zones
The Idaho Power website continued to provide information related to wildfire safety in 2024:
• Searchable map of PSPS zones by customer address
• Summer outage preparation
• How Idaho Power protects the grid, including mitigation efforts

•. • Power Company • • 2025
2024 WMP Communication Recap
10.5. Idaho Power Internal Communications—Employees
Idaho Power communicated wildfire messages to its employees in a variety of ways:
• News Scans
• How customers can help prevent wildfires
• An active PSPS event page that provides details of active PSPS areas and outage
duration information
Additionally:
• Postcards to all customers in PSPS zones to inform them of program details
• Wildfire themed customer newsletter (Connections) to all customers in May
• Wildfire-themed customer email to all customers with email addresses on file
(approx. 350,000) in May
• A "pop-up" on the My Account webpage encouraging customers to update
contact information
• Post fire-season postcards to all Oregon customers in November for invitation to
public meetings
• Customer survey to learn more about customer perception, support, and knowledge
of fire-mitigation efforts, including PSPS.
for all employees
• Leader communications
• GIS-based visual communication of risk zones and affected overhead lines
• Online training for employees -• by the WIVIP
• In-person, hands-on, training for certain field employees
• Say What?—Short explanations of high-interest topics that may be in the news or
circulating on social -•

Wildfire Mitigation Plan 2025 Idaho Power Company
11. Performance Monitoring and Metrics
11.1. Wildfire Mitigation Plan Compliance
The chief operating officer (COO) is the designated oversight officer for the Idaho Power
Wildfire Mitigation Plan (WMP). The vice president (VP) of Planning, Engineering and
Construction is responsible for compliance monitoring, necessary training, and annual review of
this WMP.
11.2. Internal Audit
Idaho Power's internal audit department, Audit Services, periodically conducts an independent
and objective evaluation of the WMP to assess compliance with policies and procedures and
evaluate achievement of the Plan's objectives. Idaho Power's Compliance department also
periodically reviews Idaho Power's compliance with federal reliability standards regarding
vegetation management practices.
11.3. Annual Review
Idaho Power conducts an annual review of its WMP and incorporates necessary updates prior
to wildfire season.
11.4. Wildfire Risk Map
The Wildfire Risk Map was originally established in 2020 by an external consultant. As noted in
Section 3, Idaho Power reconducted risk modeling in 2023 and included updated information
on population, vegetation, and climatic conditions. In 2024, Idaho Power began the process of
integrating Technosylva Wildfire Analyst Enterprise (WFA-E) software into the company's
approach for wildfire risk identification and quantification. WFA-E integration is anticipated to
continue throughout the first two quarters of calendar year 2025, with operational capability
targeted prior to the start of the 2025 wildfire season. WFA-E is a cloud-based SaaS platform
that provides on-demand wildfire spread prediction capabilities to support operational
response, consequence-based scenario analysis, and wildfire risk forecasting. WFA-E will be
used moving forward to continue to refine Idaho Power's risk mapping process.
11.5. Situational Awareness
Idaho Power will share its Fire Potential Index (FPI) regularly and broadly with Idaho Power
personnel and contractors during wildfire season to ensure condition-specific operating
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Idaho Power Company Wildfire Mitigation Plan 2025
requirements are met. WFA-E, explained in section 11.4 above, will be used in concert with the
FPI for situational awareness purposes.
11.6. Wildfire Mitigation—Field Personnel Practices
Idaho Power crews and certain personnel are required to follow the Field Personnel Practices
when working on lines in Tier 2 and Tier 3 zones during a red FPI. Specific requirements are
found in Idaho Power's Regional WMP Operational Plans and Field Wildfire Risk Procedures
documents, which are consulted by such crews working in these areas.
11.7. Wildfire Mitigation—Operations
Each year in preparation for the fire season, Idaho Power reviews and implements:
• Temporary operating procedures for transmission lines during the fire season
• An operational strategy for distribution lines during time periods of elevated wildfire risk
during the fire season
• Use of public safety power shutoff(PSPS) as a tool of last resort to prevent Idaho Power
transmission and distribution (T&D) facilities from becoming a wildfire ignition source or
contributing to the spread of wildfires
11.8. Wildfire Mitigation—T&D Programs
This section lists metrics used to evaluate Idaho Power's asset management and vegetation
management programs. The metrics in Table 19 are based on progress made toward
completing mitigation activities, such as quantities of inspected units. Work is identified and
prioritized each year and approved by executive management. Idaho Power's goal is to
complete 100% of the work plan each year; however, emergencies or other unplanned events
can occur and disrupt the annual work plan. All work is completed in accordance with safety
and applicable requirements and industry standards.
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Wildfire Mitigation Plan 2025 Idaho Power Company
Table 19
T&D programs metrics
Transmission
Transmission Asset Management Programs Description
Aerial Visual Inspection Program Perform annual patrols and document identified defects according to
priority.Complete repairs according to priority definition.
Ground Visual Inspection Program Perform annual patrols and document identified defects according to
priority.Complete repairs according to priority definition.
Detailed Visual(High Resolution Photography) Perform 10-year cycle patrols and document identified defects
Inspection Program according to priority.Complete repairs according to priority
definition.
Wood Pole Inspection and Treatment Program Perform 10-year cycle inspection and treatment and document
identified rejects according to priority.Complete replacement
according to priority definition.
Cathodic Protection and Inspection Program Perform 10-year structure-to-soil potential testing on select towers
with direct-buried anodes.Perform 10-year rectifier and ground-bed
testing on impressed current corrosion protection(ICCP)systems.
Annually inspect and record DC voltage and current readings of
rectifiers.Complete repairs and adjustments.
Wood Pole Wildfire Protection Program Install fire mesh wraps on selected poles.
Distribution
Distribution Asset Management Programs Description
Wood Pole Inspection and Treatment Program Perform 10-year cycle inspection and treatment and document
identified rejects according to priority.Complete replacement
according to priority definition.
Line Equipment Inspection Program Complete annual inspections and data analysis and mitigate defects
Ground Detailed Inspection Program Perform annual patrols and document identified defects according to
priority.Complete repairs according to priority definition.
Thermography(Infra-Red)Inspections Complete inspections of targeted lines and equipment using thermal
imaging(infrared)cameras.
Distribution Infrastructure Hardening Program Complete annual work plan.
Replace"small conductor"with new 4ACSR or larger conductor.
Replace or repair damaged conductor.
Re-tension loose conductors,including"flying taps"and slack spans
as required.
Replace wood-stubbed poles with new wood poles.
Replace white and yellow square tagged poles with new wood poles.
Replace wood crossarm with new fiberglass crossarms.
Replace steel insulator brackets with new steel pins/fiberglass
crossarms.
Replace wedge deadends on primary taps with new polymer
deadend strain insulators.
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Idaho Power Company Wildfire Mitigation Plan 2025
Replace aluminum deadend strain insulators with new polymer
deadend strain insulators.
Replace porcelain switches with new polymer switches.
Replace hot line clamps.
Replace aluminum stirrups.
Install avian cover.
Relocate arresters.
Install bird/animal guarding.
Update capacitor banks.
Replace swelling capacitors.
Replace oil-filled switches with vacuum style.
Replace porcelain switches with polymer switches.
Replace expulsion arrestors.
Install disconnect switches on CSP transformers.
Install avian cover.
Update down guys
Replace/Install down-guy insulators with fiberglass insulators.
Tighten down guy.
Tighten hardware.
Correct third-party pole attachment violations(report to Joint Use
department).
Replace expulsion fuses.
Vegetation Management
Transmission Description
Pre-Fire Season Inspection and Mitigation Perform annual pre-fire season inspections no later than June 15 of
each year and mitigate noted"hot spots."
Line Clearing Cycles:Strive to maintain 3-year Complete annual cycle pruning work plan.
cycle for valley areas&6-year cycle for mountain
areas
Tree Removals—Hazard Trees Remove targeted hazard trees.
Targeted Pole Clearing Complete annually targeted structures.
100%QA/QC Audits in Tier 3 and Tier 2 zones Complete annually QA/QC audits.
Distribution Description
Pre-Fire Season Inspection and Mitigation Perform annual pre-fire season inspections no later than June 15 of
each year in Tier 3 and Tier 2 zones and mitigate noted"hot spots."
Line Clearing Cycle:Strive to maintain 3-year cycle Complete annual cycle pruning work plan.
Mid-Cycle Pruning in Tier 3 and Tier 2 zones Complete annual mid-cycle pruning work plan in Tier 3 and Tier 2
zones.
Tree Removals—Cycle Busters/Hazard Trees Complete annual cycle pruning work plan.
Targeted Pole Clearing Complete annually targeted structures.
100%QA/QC Audits in Tier 3 and Tier 2 zones Complete annually QA/QC audits.
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Wildfire Mitigation Plan 2025 Idaho Power Company
11.9. Long-term Metrics
Idaho Power measures the performance of the WMP and its effectiveness over time in part by
tracking outage counts in wildfire risk zones during wildfire season and the progress made
toward completing mitigation programs and activities. Vegetation management and grid
hardening work is expected to reduce outages and improve reliability in wildfire risk zones.
The following outage causes were established as baseline potential drivers of ignition and are
tracked annually for each wildfire risk zone:
• Tree/Vegetation Contact
• Equipment Failure
• Loose Hardware
• Corrosion
• Animal Contact
The use of outage data to gauge overall WMP performance is expected to be a long-term
metric and take several years to develop trendlines and averages to draw definitive conclusions
and a causal relationship to wildfire mitigation activities. Table 20 summarizes outage counts in
wildfire risk zones during the 2024 wildfire season (May 10 through October 20) and provides
the percent change compared to a baseline that includes the average annual wildfire season
outage counts for the 2019 through 2021 wildfire seasons. It should be noted that Idaho Power
implemented Enhanced Protection Settings for the first time during the 2024 fire season, which
increased the total number of outages.
Table 20
Outage metrics
Wildfire Risk Zone Outage Metrics—by Cause Code
Cause Code 2024 Outage %Change Compared to
Count* Baseline
Tree/Vegetation 156 17%
Equipment Failure 65 17%
Small Animal or Bird 116 27%
Corrosion 16 0%
Foreign Object Contact 4 -8%
Loose Hardware 5 7%
*The total number of outage counts during the 2024 wildfire season was 18%higher than the baseline.This is primarily due to
the more sensitive Enhanced Protection Settings implemented for the first time during the 2024 fire season.
In 2023, Idaho Power began analyzing and evaluating the effectiveness of overhead circuit
"hardening" practices by calculating reliability performance indices and outage rates per
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Idaho Power Company Wildfire Mitigation Plan 2025
100 line-miles for hardened feeders before and after the hardening work was complete.
The reliability performance indices assessed include the System Average Interruption
Frequency Index (SAIFI), System Average Interruption Duration Index (SAIDI), and the outage
rate for circuits that have had WMP hardening.
Hardened circuits, or "feeders," were compared to baseline feeders, which are defined as all
other distribution feeders that do not have completed WMP hardening projects. This analysis is
most informative, with several years of actual before and after data to calculate valid
comparisons and identify system hardening benefits. There are now approximately two years of
history since initial WMP hardening projects were completed in late 2021. Results of the
analysis to date indicates improvement by hardening as shown in Table 21. Idaho Power will re-
evaluate and calculate specific results over the coming years as more "post-hardening"
time has passed.
Table 21
Overhead circuit hardening reliability improvements
Overhead Circuit Hardening Reliability
Improvements
SAIR %improvement with WMP hardening 25%
SAIDI%improvement with WMP hardening 26%
Outage rate%improvement with WMP 13%
hardening
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Idaho Power Company Oregon Wildfire Requirements and Recommendations
Appendix A
Wildland Fire Preparedness and Prevention Plan
Appendices

N IDAHo POWER,
Wildland Fire Preparedness
and Prevention Plan

The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
Table of Contents
Tableof Contents...........................................................................................................................i
1. Plan Overview .........................................................................................................................1
A. Intent of Plan..................................................................................................................1
B. Scope of Plan..................................................................................................................1
2. Situational Overview and Applicability.................................................................................... 1
A. Wildfire Season .............................................................................................................. 1
B. Wildfire Risk Zones.........................................................................................................2
C. Fire Potential Index ........................................................................................................2
D. Decision Making for Field Work Activities......................................................................2
3. Preparedness—Tools and Equipment.....................................................................................4
A. Required Personal Protective Equipment.......................................................................4
B. Required Tools and Equipment ......................................................................................5
C. Land Management Agency Restrictions and Waivers.....................................................6
4. Prevention—Practices of Field Personnel ...............................................................................7
A. General Employee Practices...........................................................................................7
B. Behaviors Relating to Vehicles and Combustion Engine Power Tools ............................9
5. Reporting ..............................................................................................................................11
A. Fire Ignition ..................................................................................................................11
B. Fire Reporting...............................................................................................................11
6. Training.................................................................................................................................11
7. Roles and Responsibilities.....................................................................................................12
8. Audit .....................................................................................................................................12
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
Page ii

The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
I. Plan Overview
A. Intent of Plan
The purpose of this Wildland Fire Preparedness and Prevention Plan (Plan) is to provide guidance to
Idaho Power Company(IPC) employees to help prevent the accidental ignition and spread of wildland
fires (wildfires) associated with employee work activities in locations and under conditions where there
is a heightened risk of wildfire. It is expected that all applicable IPC employees be aware of the provisions
of this Plan, operate in accordance with the Plan, and conduct themselves in a fire-safe manner.
B. Scope of Plan
The scope of this Plan includes tools, equipment, and field behaviors IPC employees incorporate when
working in locations and under conditions where there is a heightened risk of wildfire.
Operations of Transmission and Distribution (T&D) lines facilities,vegetation management, and T&D
lines programs that mitigate wildfire risks are not included in this Plan; they are referenced in the
separate Wildfire Mitigation Plan.
2. Situational Overview and Applicability
A. Wildfire Season
The provisions of this Plan shall be applicable during wildfire season. Idaho's wildfire season is defined by
Idaho Code § 38-115 as extending from May 10 through October 20 each year, or as otherwise extended
by the director of the Idaho Department of Lands (IDL). Oregon's wildfire season is designated by the
State Forester each year pursuant to Oregon Revised Statute §477.505 and typically begins in June.
Should any local, state, or federal government land management agency(i.e.,the Bureau of Land
Management [BLM], U.S. Forest Service, Oregon Department of Forestry, Idaho Department of Lands,
etc.) issue any wildfire related order that extends wildfire season beyond that specified above,that
agency's order shall govern.
Many variables—such as drought conditions, weather, and fuel moisture—can impact fire potential.
Flexibility,judgment, attention to current and forecasted field conditions, and attention to governmental
agency issued wildfire orders are necessary such that operational practices can be adjusted accordingly.
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
B. Wildfire Risk Zones
IPC's Wildfire Mitigation Plan includes a Wildfire Risk Map of IPC's service area.This Wildfire Risk Map
may be accessed through geographic information system (GIS) applications. All lands in the vicinity of IPC
facilities are mapped as Tier 2 (colored yellow on maps),Tier 3 (colored red on maps) or areas of minimal
wildfire risk (i.e., not within a Tier 2 or Tier 3 zone).Tier 2 and Tier 3 zones are designated as wildfire risk
zones (WRZ).The provisions of this Plan shall apply to work activities taking place during wildfire season
in these WRZs.
C. Fire Potential Index
IPC's Atmospheric Sciences department has developed a Fire Potential Index (FPI) rating system that
forecasts wildfire potential across IPC's service area.The FPI considers many current and forecasted
elements such as meteorological (winds—surface and aloft,temperatures, relative humidity,
precipitation, etc.) and fuel state (both live and dead).The FPI is designed and calibrated for IPC's service
area; specifically,those areas in proximity to IPC transmission, distribution, and generation facilities.
The FPI consists of a numerical score ranging from 1 (very green, wet fuels with low to no wind and high
humidity)to 16 (very brown and dry, both live and dead dry fuels with low humidity and high
temperatures).The FPI scores are grouped into the following three index levels:
• Green: FPI score of 1 through 11
• Yellow: FPI score of 12 through 14
• ■: FPI score of 15 through 16
During wildfire season, IPC will determine a daily FPI as described in Section 5 of the WMP.This weather
forecast and FPI dashboard is contained within IPC GIS viewers available to all IPC employees.
D. Decision Making for Field Work Activities
Employees working in the field shall be aware of current and forecasted weather and field conditions.
Awareness of these conditions, and exercising appropriate judgment, is essential when considering
whether to undertake work activities when combinations of high temperatures, low humidity, dry fuels,
and/or wind are present or forecasted to be present.
The following process steps shall apply to employees and crews contemplating field work during wildfire
season.
Planned or Scheduled Work Activities
1. Fire Potential Indices:
1.1. Employees working in the field—NOT working on transmission or primary
distribution lines should:
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
1.1.1. Be aware of the current and forecasted weather and the FPI level for the area
where the work will be performed, through the FPI dashboard.
1.1.2. Once the FPI level for the work zone is identified, proceed with work but
consider using Prevention—Practices of Field Personnel (see Section 6 of
this Plan).
1.2. Employees working in the field—working on transmission or primary distribution
lines should:
i. Be aware of the current and forecasted weather and the FPI level for the area
where the work will be performed.
1.2.1. Once the FPI level for the work zone is identified, proceed as follows for each
FPI level:
1. Green FPI in All Zones: Proceed with the work. Evaluate need for utilizing
Prevention—Practices of Field Personnel (see section 4 of this Plan).
2. Yellow FPI in All Zones: Proceed with the work. Evaluate need for utilizing
Prevention—Practices of Field Personnel (see section 4 of this plan).
3.
a. In Normal Zone: Proceed with the work. Consider and evaluate need
for utilizing Prevention—Practices of Field Personnel (see Section 4 of this
plan).
b. In Tier 2 Zone: Proceed with the work. However, it is a requirement to follow
Prevention—Practices of Field Personnel (see Section 4 of this plan).
c. In Tier 3 Zone: STOP. No planned work activities shall take place unless
approved by operations level manager. Work consideration will be
restoration of electric service or work deemed critical to providing safe,
reliable electric service. If work is approved to proceed it is a requirement to
follow Prevention—Practices of Field Personnel (see Section 4 of this plan).
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
Proceed with Work Proceed with Work
Higher 15 to 16 Utilize Prevention/Practices Utilize Prevention/Practices STOP/NO WORK
(Red) of Field Personnel of Field Personnel
(Evaluate Conditions and REQUIRED
Utilize as Needed)
Proceed with Work Proceed with Work Proceed with Work
Fire
Potential Elevated 12 to 14 Utilize Prevention/Practices Utilize Prevention/Practices Utilize Prevention/Practices
Poten
Index tial (Yellow) of Field Personnel of Field Personnel of Field Personnel
(Evaluate Conditions and (Evaluate Conditions and (Evaluate Conditions and
Utilize as Needed) Utilize as Needed) Utilize as Needed)
Proceed with Work Proceed with Work Proceed with Work
Normal 1 to 11 Utilize Prevention/Practices Utilize Prevention/Practices Utilize Prevention/Practices
(Green) of Field Personnel of Field Personnel of Field Personnel
(Evaluate Conditions and (Evaluate Conditions and (Evaluate Conditions and
Utilize as Needed) Utilize as Needed) Utilize as Needed)
None Tier 2
2. Land Management Agency Restrictions: Follow the requirements and restrictions of any
wildfire restrictions related order issued by local, state, or federal land
management agencies.
a) As soon as reasonably practicable, upon receiving knowledge of an order, the
Environmental Services department will notify, via email, operations leadership
within Power Supply, Customer Operations and Business Development, and T&D
Engineering and Construction of wildfire-related requirements and restrictions
orders issued by local, state, or federal land management agencies.
Emergency Response and Outage Restoration Work Activities:
Follow the same steps as identified above for planned work activities. However, it is recognized that the
nature of emergency response and outage restoration situations will often require exceptions to the
above. In these situations, leadership should be consulted, and appropriate judgment should be used
given the nature of the emergency or outage at hand.
3. Preparedness—Tools and Equipment
A. Required Personal Protective Equipment
Standard IPC personal protective equipment (PPE) shall be worn in accordance with the IPC
Safety Standard.
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
When entering a designated fire area being managed by the BLM or the U.S. Forest Service, additional
PPE requirements may be required by those agencies.These typically include:
• Hardhat with chinstrap
• Long sleeve flame-resistant (FIR) shirt and FIR pants
• Leather gloves
• Exterior leather work boots, 8" high, lace-type with Vibram type soles
• Fire shelter
B. Required Tools and Equipment
Employees NOT working on transmission or distribution lines: Standard tools and equipment in
accordance with the IPC Safety Standard and Fleet Services.
Employees working on transmission or distribution lines: IPC and the State of Idaho BLM entered into a
March 2019 Master Agreement that governs various IPC and BLM interactions, including wildfire
prevention related provisions. IPC has elected to also apply these requirements to all work activities
taking place on all WRZ in Idaho, Nevada, Montana, and Oregon. These requirements include the
following:
• During the wildfire season (May 10—October 20) or during any other wildfire season ordered by
a local, state, or federal jurisdiction, IPC, including those working on IPC's behalf, will equip at
least one on-site vehicle with firefighting equipment, including, but not limited to:
• Fire suppression hand tools (i.e., shovels, rakes, Pulaskis, etc.).
• A 16-to 20-pound fire extinguisher.
• A supply of water, sufficient for initial attack, with a mechanism to effectively spray the water
(i.e., backpack pumps, water sprayer, etc.).This requirement to carry water is dependent on
the vehicle type and weight restrictions. For example, a mini-excavator would not be
required to carry water since there is no safe way to do so, or a loaded bucket truck may not
be required to carry water because of weight limitations.
• At a minimum, equip each truck that will be driven in the WRZs during wildfire season with at
least:
• One round, pointed shovel at least 8 inches wide, with a handle at least 26 inches long
• One axe or Pulaski with a 26-inch handle or longer
• A combination of shovels, axes, or Pulaskis available to each person on the crew
• One fire extinguisher rated no less than 2A:10BV(5 pounds)
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
• 30 to 200 gallons of water in a fire pumper and 5-gallon back packs
IPC personnel will be trained to use the above tools and equipment to aid in extinguishing a fire ignition
before it gets out of control. In the event of a fire ignition, IPC personnel present at the time of the
ignition will take action that a reasonably prudent person with that person's training and experience
would take to control the fire ignition while still accounting for their own personal safety.
C. Land Management Agency Restrictions and Waivers
The Environmental Services department will notify operations leadership within Power Supply, Customer
Operations and Business Development, and T&D Engineering and Construction of any wildfire-related
requirements and restrictions orders issued by local, state, or federal land management agencies.Typical
orders issued each fire season include the following:
• BLM. During BLM's Stage II Fire Restrictions, IPC's Environmental Services department will obtain
an appropriate waiver. Field personnel shall take appropriate precautions when conducting work
activities that involve an internal combustion engine, generating a flame, driving over or parking
on dry grass,the possibility of dropping a line to the ground, or explosives. Precautions include a
Fire Prevention Watch person who will remain in the area for 1 hour following the cessation of
that activity. Also, IPC personnel will not smoke unless within an enclosed vehicle, building, or
designated recreation site or while stopped in an area at least 3 feet in diameter that is barren or
cleared of all flammable materials.All smoking materials will be removed from work sites. No
smoking materials are to be discarded.
• State of Oregon Department of Forestry(ODF). Prior to each summer fire season,the ODF
issues a "Fire Season Requirements" document that specifies required tools, equipment, and
work practices. In addition to State of Oregon lands, IPC has elected to apply these requirements
to all work activities taking place on all WRZ, BLM lands, and Forest Service lands within the
State of Oregon. Go to oregon.gov/ODF/Fire/Pages/Restrictions.aspx for ODF's Fire Season
Requirements order.
• Other sites for reference that contain fire restriction orders include the following.This is not an
exclusive list.The Environmental Services department is expected to be familiar with sites where
land management agencies post relevant orders:
• Oregon— Blue Mountain Interagency Fire Center at bmidc.org/index.shtml
• Nevada—Fire Information at nevadafireinfo.org/restrictions-and-closures
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
4. Prevention—Practices of Field Personnel
A. General Employee Practices
The below listing includes, but is not limited to, practices and behaviors employees shall incorporate
depending on the FPI and level of WRZs during fire season.
1. Daily tailboards must include discussion around fire mitigation planning. Discussion topics
include, but are not limited to, the following:
• Items 2 through 7 below
• Water suppression
• Hand tools
• Welding blankets
• Mowing high brush areas (weed wacker)
• Watering down the worksite before setting up equipment
2. Weather conditions and terrain to be worked shall be considered and evaluated. Items to
be considered include, but are not limited to, the following:
a) Identify the FPI for the area being worked (see Section 5.2 of the WMP).
2.1. Monitor weather forecasts, and wind and humidity conditions.
2.2. Identify surroundings (i.e., wildland-urban interface, BLM lands, Forest Service lands,
proximity to any homes and structures, etc.).
2.3. Identify local fire departments and locations.
2.4. Evaluate the terrain you are working in (steep or flat).
2.5. Consider whether the work will occur during the day or at night.
3. Work procedures and tools that have potential to cause a spark or flash shall be
considered and evaluated. Items to be considered include, but are not limited to,
the following:
• Performing energized work
• Grinding or welding
• Trees contacting electrical conductors
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
• Hot saws
• Chainsaws
• Weed wackers
• Sawzalls
4. Monitoring the worksite throughout the project.
It is imperative that all crews and equipment working in the WRZs areas are continuously
monitoring and thoroughly inspecting the worksite throughout the project.This includes prior to
leaving the work area for the night or before moving on to the next structure.
5. Employee cooking stoves.
• When working in remote locations, often employees bring food that needs to be cooked. Open
flames are not allowed. Cook stoves may be permitted by leadership but special precautions
must be followed to use them:
• The stove or grill must be in good repair and of sturdy construction.
• Stoves must be kept clean; grease build up is not allowed.
• Fueling of the stove must follow the fueling procedures when liquid fuels are used.
• Cooking must be in areas free of combustible materials.
6. Smoking on the job site.
• Carelessly discarded smoking materials can result in wildfire ignition.The following practices
shall be followed:
• Do not discard any tobacco products from a moving vehicle.
• Smoking while standing in or walking through forests or other outdoor areas when IPC's FPI
rating is above a Green level is prohibited.
• All employees must smoke only in designated areas, and smoking materials must be
disposed of in half-filled water bottles or coffee containers half-filled with sand. Smoking
materials shall not be discarded on any site.
7. Post job site inspection.
Final inspection or post-checking the work site for any ignition hazards that may remain is important.
Post-checking the work will help ensure the hazards were mitigated and provide a final chance to see if
any new hazards or hot spots exist before leaving the work site.
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
B. Behaviors Relating to Vehicles and Combustion Engine
Power Tools
It is important to consider work procedures, equipment conditions, employee actions, potential causes,
and other sources that could lead to fire ignition. Some work practices may be performed on roadways
that have little to no risk of fire ignition. Leadership should consider scheduling off-road equipment use
during times of Green level FPI. Employees should also consider alternative tools, work methods, or
enhanced suppression tools to reduce the risk or spread of fire.
1. Additional heat may bring vegetative materials to an easier point of ignition. This includes,
but is not limited to, the following vehicles:
• Pickups
• Crew cabs
• Line-beds
• Bucket trucks (large and small)
• Backhoes
• Excavators and rope trucks
• Any other motorized equipment
2. Vehicle Procedures:
a) Inspect all engine exhaust, spark arresters, and electrical systems of vehicles used
off road daily for debris, holes, or exposed hot components and ensure heat shields
and protective components are in place.
2.1. Conduct inspections of the vehicle undercarriage before entering or exiting the
project area to clear vegetation that may have accumulated near the vehicle's
exhaust system.
2.2. Vehicles shall be parked overnight in areas free from flammable vegetation at a
minimum distance of 10 feet.
2.3. Vehicles and equipment will not be stationary or in use in areas where grass, weeds,
or other flammable vegetation will be in contact with the exhaust system.
2.4. If there is no other workable option for the location that doesn't include weeds,
grass, or other flammable vegetation, the vegetation and debris will need to
be removed.
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
2.5. Consider using a fire-resistant material, such as a welding blanket to cover flammable
material to act as a heat shield; fire blankets may be a suitable option to avoid
removal of vegetation.
3. Hot brakes on vehicles and equipment:
a) Park vehicles in areas free of combustible materials.
3.1. Hot brake emergency parking during times of Yellow or Red FPI shall be cleared of
combustible materials for a distance of at least 10 feet from the heat source.
4. Fueling procedures:
a) Tools or equipment should NOT be fueled while running.
4.1. A cool-down period must be given to allow equipment time to no longer be
considered a fire risk.
4.2. Allow for a 10-foot radius from all ignition sources.
4.3. Clear any combustible debris from the immediate area.
4.4. Never smoke while fueling.
4.5. Designate fueling areas for all gas-powered tools.
5. Combustion engine power tools:
Poorly maintained or missing spark arrester screens may allow sparks to escape and cause
ignition of vegetation. Ensure proper spark arrester screens are in place for the following tools:
• Generators
• Pony motors
• Pumps
• Chainsaws
• Hot saws
• Weed wacker
• Brush hog
Inspect spark arresters daily; clean or replace when clogged, damaged, or missing or remove
from service until repaired.
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
5. Reporting
A. Fire Ignition
All fire ignitions shall be immediately reported to regional or system dispatch. Dispatch will notify local
fire authorities. All work shall immediately stop, and reasonably prudent steps taken to extinguish the
fire with available tools, water, and equipment in light of the individual's training and experience. If the
fire gets too large to safely contain or extinguish, ensure all employees are accounted for and get to a
safe location.
B. Fire Reporting
When reporting a fire ignition to regional or system dispatch provide the following information:
• Your name
• Location—Reference points, including an address, road or street name, cross streets, mountain
range, GPS coordinates, as applicable.
• Fire information
• Size and behavior of the fire
• Weather conditions
6. Training
Each employee who performs work in WRZ shall be trained on the content of this document and be
required to complete annual refresher courses through the Workday system. Employees are required to
complete fire extinguisher and fire shelter training annually as part of lineman safety compliance.
Documentation of all training shall be retained in Workday.
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Idaho Power Company The Wildland Fire Preparedness and Prevention Plan
7. Roles and Responsibilities
Employee 1. Be familiar with the requirements specified in this Plan and operate in accordance
with this Plan.
2. Be aware of daily weather forecast and FPI level.
3. Be aware of whether field work will be performed in a WRZ.
Crew Foreman and 1. Ensure direct report employees are familiar with and follow Plan requirements.
Front-Line Leaders 2. Ensure the crew or team conducts field operations in accordance with this Plan.
3. Be aware of daily weather forecast and FPI level(by viewing the FPI dashboard or
by calling into dispatch or a leader):
a) Ensure employees are aware of the FPI level.
b) Ensure work practices comply with this Wildland Fire Preparedness and
Prevention Plan when the FPI is"Red"and the WRZ is Tier 2.
c) Ensure no work takes place when FPI is"Red"and the WRZ is Tier 3. Discuss
any exceptions with manager.
4. Ensure annual training of employees is completed prior to wildfire season.
5. Ensure required tools and equipment are in place prior to wildfire season.
Manager(Regional 1. Ensure crew foremen and front-line leaders understand they are to operate in
Operations Manager,Area accordance with Plan requirements.
Manager,T&D Construction 2. Support crew foremen and front-line leaders in scheduling training and making
Manager) required tools and equipment available.
3. View daily weather forecast and FPI dashboard:
a) Authorize any exceptions to working when FPI is"Red"and the WRZ is Tier 3.
b) Ensure specified audits are completed in a timely manner.
Atmospheric Sciences 1. Provide daily weather forecast and update the FPI dashboard contained within
Department the IPC Enviro Viewer.
Environmental Services 1. Monitor local,state,and federal land management agencies for any wildfire
Department restriction orders issued.
2. Communicate content of any orders issued to Power Supply,Customer Operations
and Safety,and Planning Engineering and Construction leadership.
Operations Procurement 1. Ensure contractors have a copy of this Plan and contractual requirements are in
Department place to ensure adherence to the Plan.
Vice-President of Planning, 1. Ensure annual review/update of this Plan is conducted following the completion
Engineering and Construction of each wildfire season.
(VP of PEC)
8. Audit
Prior to the start of wildfire season (May 10), all vehicles associated with work on transmission and
distribution lines will be audited by leadership to ensure those working in WRZs are properly equipped
with firefighting equipment.The following checklist must be completed, dated, and signed by a member
of leadership (front-line supervisor or above) and kept with the crew or individual until fire season has
ended (Oct 20). A copy of each audit checklist shall be sent to the respective manager and
senior manager.
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The Wildland Fire Preparedness and Prevention Plan Idaho Power Company
Wildland Fire Preparedness Audit Checklist
Inspector:
Signature:
Date:
Crew:
Line Crew:
At least one vehicle will be equipped with the following:
✓ Fire suppression hand tools (shovels, Pulaski, axes, etc.)for each member of the crew
✓ A 16-to 20-pound fire extinguisher(or two, 10-pound fire extinguishers)
✓ A supply of water, sufficient for initial attack, with an effective spraying mechanism
(i.e., backpack pumps, water sprayer, etc.)
✓ A 30-to 75-gallon mechanical fire pumper
Individual Truck:
✓ One round, pointed shovel at least 8 inches wide, with a handle at least 26 inches long.
✓ One axe or Pulaski with a 26-inch handle or longer.
✓ A combination of shovels, axes, or Pulaskis to each person on the crew.
✓ One fire extinguisher rated no less than 2A:10BV(5 pounds).
✓ A supply of water, sufficient for initial attack,with an effective spraying mechanism
(i.e., backpack pumps, water sprayer, etc.).This requirement to carry water is dependent on the
vehicle type and weight restrictions. For example, a mini-excavator would not be required to
carry water since there is no safe way to do so, or a loaded bucket truck may not be required to
carry water because of weight limitations.
PPE: IPC and BLM standards. Each employee performing construction or maintenance activities will be
required to have the following PPE:
✓ Hard hat
✓ Safety glasses
✓ Hearing protection
✓ Long sleeve FIR shirt FIR pants
✓ Leather gloves
✓ Exterior leather work boots 8" high lace type with Vibram type soles
✓ Fire shelter
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Oregon Wildfire Requirements and Recommendations Idaho Power Company
Appendix B
Public Safety Power Shutoff(PSPS) Plan
Appendices

M41W -0IQAHO R.
Idaho Power Company's
Wildfire Public Safety
Power Shutoff Plan
December 2024
© 2024 Idaho Power

Idaho Power Company Wildfire Public Safety Power Shutoff Plan
Table of Contents
Tableof Contents...........................................................................................................................i
Listof Figures............................................................................................................................... iii
1. Introduction ............................................................................................................................ 1
2. List of Acronyms......................................................................................................................2
3. Definitions...............................................................................................................................3
4. Public Safety Power Shutoff Overview....................................................................................4
5. Scope.......................................................................................................................................4
6. Key Tenets...............................................................................................................................5
7. Wildfire Zones.........................................................................................................................5
8. PSPS Implementation Considerations.....................................................................................5
8.1. Fire Potential Index ........................................................................................................5
8.2. National Weather Service Red Flag Warning..................................................................6
8.3. NWS Fire Weather Forecasts..........................................................................................7
8.4. Publicly Available Weather Models................................................................................7
8.5. Idaho Power Weather Model .........................................................................................8
8.6. Storm Prediction Center Fire Weather Outlooks............................................................8
8.7. Current Weather Observations ......................................................................................8
8.8. National Significant Wildland Fire Potential Forecast Outlook.......................................8
8.9. GBCC Morning Briefing...................................................................................................9
8.10. GBCC Current and Predicted ERC and F100....................................................................9
8.11. Fire Agency Input............................................................................................................9
8.12. De-Energization Windspeed Considerations ..................................................................9
8.13. Alternative Protective Measures....................................................................................9
8.14. Real-time Field Observations........................................................................................10
8.15. Other............................................................................................................................10
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
9. Responsibilities .....................................................................................................................10
9.1. Load Serving Operations...............................................................................................10
9.2. Atmospheric Science ....................................................................................................11
9.3. Transmission and Distribution Engineering and Reliability...........................................11
9.4. Customer Operations Support and Regional Operations..............................................12
9.5. Substation Operations..................................................................................................13
9.6. Corporate Communications .........................................................................................13
9.7. Safety ...........................................................................................................................14
9.8. Customer Service..........................................................................................................14
10. PSPS Operations....................................................................................................................14
10.1. Preparedness................................................................................................................14
10.1.1. Community Preparedness ...................................................................................15
10.1.2. Training and Exercises .........................................................................................16
10.2. Wildfire Season Operations..........................................................................................16
10.2.1. Situational Awareness Activities..........................................................................16
10.2.2. Key Grid Interdependent Utilities and Agencies..................................................16
10.3. Proactive Communications...........................................................................................17
10.3.1. Notifications and Emergency Alerts ....................................................................17
10.4. PSPS Phases..................................................................................................................19
10.4.1. Phase 1 & PSPS Assessment Team Activation......................................................19
10.4.2. Phase 2................................................................................................................20
10.4.3. Phase 3................................................................................................................21
10.4.4. Phase 4................................................................................................................21
10.4.5. Post-incident Review...........................................................................................22
11. Financial Administration .......................................................................................................23
12. Reporting ..............................................................................................................................23
13. After-Action Report...............................................................................................................23
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
14. Training .................................................................................................................................23
15. Exercises................................................................................................................................24
List of Figures
Figure 1
PSPS preparedness cycle..........................................................................................................15
Figure 2
Possible PSPS event communication timeline..........................................................................18
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
1. Introduction
To keep Idaho Power's customers and the communities it serves safe and continue improving
the resiliency of Idaho Power's transmission and distribution facilities, Idaho Power developed
and implemented a Wildfire Mitigation Plan (WMP) in 2021. The fundamental goals of Idaho
Power's WMP are to reduce wildfire risk associated with the company's transmission and
distribution (T&D) facilities and associated field operations as well as to improve the resiliency
of Idaho Power's T&D system in a wildfire event, independent of the ignition source. The WMP
is reviewed and updated annually.
As part of its operational mitigation practices, Idaho Power developed a Public Safety
Power Shutoff Plan (PSPS Plan or Plan) to proactively de-energize electrical facilities when
appropriate to reduce wildfire risk. This Plan identifies the relevant considerations,
process flow, and implementation protocol before, during, and after a PSPS event. The Plan is
active during wildfire season and is reviewed and updated as needed on an annual basis.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
2. List of Acronyms
AAR—After Action Review
BLM—Bureau of Land Management
COO—Chief operations officer
ECMWF—European Centre for Medium-Range Forecasts
EMT—Emergency Management Team
ERC—Energy Release Component
F100-100-Hour Fuel Moisture
FPI—Fire Potential Index
FWW—Fire Weather Watch
GBCC—Great Basin Coordination Center
GIS—Geographic Information System
IPUC—Idaho Public Utility Commission
IRWIN—Integrated Reporting of Wildland-Fire Information
LSO—Load Serving Operations
NIFC—National Interagency Fire Center
NOAA—National Oceanic and Atmospheric Administration
NWS—National Weather Service
OPUC—Oregon Public Utility Commission
PEC—Planning, Engineering and Construction
PSPS—Public Safety Power Shutoff
RFW—National Weather Service issued Red Flag Warning
SME—Subject-matter expert
T&D—Transmission & Distribution
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
TDER—Transmission & Distribution Engineering and Reliability
UKMET—United Kingdom Meteorological Office
VMP—Vegetation Management Program
WMP—Wildfire Mitigation Plan
WRF—Weather Research and Forecasting
3. Definitions
(1) Critical Facilities—Refers to the facilities identified by Idaho Power that,
because of their function or importance, have the potential to threaten life,
safety, or disrupt essential socioeconomic activities if their services
are interrupted.
(2) ESF-12—Refers to Emergency Support Function-12 and is the Idaho Power
liaison from the State Office of Emergency Management for energy utilities
issues during an emergency for both Idaho and Oregon.'
(3) Exercise—Refers to planned activities and assessments that ensure continuity
of operations, provide and direct resources and capabilities, and gather
lessons-learned to develop core capabilities needed to respond to incidents.
(4) Community—Refers to a group of people that share goals,
values, and institutions.2
(5) Local Emergency Manager—Refers to a jurisdiction's role that oversees the
day-to-day emergency management programs and activities.3
(6) Public Safety Partners—As defined by Idaho Power refers to ESF-12,
Local Emergency Management, and other agencies as applicable.
(7) Public Safety Power Shutoff or PSPS—A proactive de-energization of a
portion of an electric utility's electrical network, based on the forecasting and
measurement of wildfire weather conditions.
' Federal Emergency Management Institute (FEMA) National Response Framework(NRF) Emergency
Support Functions (ESF) National Response Framework I FEMA.gov.
Z FEMA definition under"Communities" (pg. 26) National Response Framework(fema.gov).
3 FEMA definition under"Local Government" (pg. 29) National Response Framework (fema.gov).
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
4. Public Safety Power Shutoff Overview
In recent years, the western United States (U.S.) has experienced an increase in the frequency
and intensity of wildland fires (wildfires). A variety of factors contribute to this trend,
including climate change, increased human encroachment in wildland areas, historical land
management practices, and changes in wildland and forest health. Recent events in western
states have increased awareness of electric utilities' role in wildfire prevention and mitigation.
To keep Idaho Power's customers and the communities it serves safe and continue improving
the resiliency of Idaho Power's T&D facilities, Idaho Power implemented a WMP in 2021
focused on situational awareness, field personnel safety practices, and operational wildfire
mitigation strategies.
As part of its operational mitigation practices, Idaho Power developed a PSPS Plan (or Plan) to
proactively de-energize electric transmission and/or distribution facilities during extreme
weather events to reduce the risk of wildfire. Based on the inherently disruptive nature of
power outages, PSPS events must be carefully evaluated under this Plan to balance wildfire risk
with potential PSPS impacts on Idaho Power customers and the communities it serves.
The unpredictable nature of wildfire and weather patterns can create challenges with
forecasting when a PSPS event should be implemented. Real-time evaluations and
decision-making are therefore important in making PSPS determinations and, depending on the
associated wildfire conditions, those determinations may result in a decision not to de-energize
or even a proactive de-energization in areas not originally anticipated to be included in a
PSPS event.
S. Scope
This PSPS Plan identifies the relevant considerations, process flow, and implementation
protocol before, during, and after a PSPS event. The Plan will be active during wildfire season
and reviewed and updated as necessary on an annual basis. Wildfire season is defined by Idaho
Code § 38-115 as extending from May 10 through October 20 each year, or as otherwise
extended by the director of the Idaho Department of Lands (IDL). Oregon's wildfire season
generally aligns with Idaho's wildfire season and is designated by the State Forester each year
pursuant to Oregon Revised Statute 477.505.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
6. Key Tenets
• Advancing the safety of Idaho Power employees, customers, and the general public
• Collaborating with key external stakeholders (agencies, counties, local governments,
public safety partners, and first responders)
• Minimizing both potential wildfire risk and power outage impacts on communities
and customers
• Maintaining reliable electric service
7. Wildfire Zones
Idaho Power's WMP identifies areas of elevated wildfire risk within its service area using a
process explained in the company's WMP. Idaho Power's risk tiers reflect Idaho Power's
informed assessment of risk relative to Idaho Power's service area only and not absolute risk.
Idaho Power color-codes the tiers—yellow for Tier 2 and red for Tier 3.
In its WMP, Idaho Power identifies operational practices specific to these zones for purposes of
reducing wildfire risk associated with the company's T&D facilities and associated field
operations and improving the resiliency of Idaho Power's T&D system in a wildfire event,
independent of the ignition source. This PSPS Plan sets forth Idaho Power's PSPS evaluation
criteria and processes, including operational and communication protocol, for implementing
a PSPS.
8. PSPS Implementation Considerations
Idaho Power will initiate a PSPS if the company determines a combination of critical conditions
exist that indicate a potential significant wildfire risk associated with Idaho Power's T&D
facilities under those known conditions. Idaho Power will evaluate as a whole (not relying on
one single factor but a combination of all factors), without limitation, the criteria set forth in
sections 8.1 through 8.15 of this Plan. The following subsections list the varying data sources
Idaho Power may consider in deciding whether to initiate a PSPS.
8.1. Fire Potential Index
In addition to the risk tier designations in its WMP, Idaho Power developed an FPI to forecast
wildfire potential across Idaho Power's service area as described in Section 5.2 of the WMP.
This tool is designed to support operational decision-making during fire season. The FPI

Wildfire Public Safety Power Shutoff Plan Idaho Power Company
converts environmental, statistical, and scientific data into an easily understood forecast of the
short-term fire threat, which could exist for different geographical areas in the Idaho Power
service area. The FPI is issued for a seven-day period to provide foresight into potential
upcoming changes in the FPI, which may trigger operational mitigation efforts, as detailed in
the WMP.
The FPI reflects key variables, such as the state of native vegetation across the service area
("green-up"), fuels (ratio of dead fuel moisture component to live fuel moisture component),
and weather (sustained wind speed and dew point depression). Each of these variables is
assigned a numeric value and those individual numeric values are summed to generate a Fire
Potential value from zero to 16, each of which expresses the degree of fire threat expected for
each 6-hour period of the seven days included in the forecast. The FPI scores are grouped into
the following index levels:
• Green: An FPI score of 1 through 11 indicates lower potential for a large fire to develop
and spread, as there is normal vegetation and fuel moisture content as well as weak
winds and high relative humidity.
• Yellow: An FPI score of 12 through 14 indicates an elevated potential for a large fire to
develop and spread, as there are lower than normal vegetation and fuel moisture
content as well as moderate winds and lower than normal relative humidity.
• Red: An FPI score of 15 through 16 indicates a higher potential for a large fire to develop
and spread, as there are well below normal vegetation and fuel moisture content as well
as strong winds and low relative humidity.
FPI information is provided internally via email, certain Geographic Information System (GIS)
viewers, and an FPI dashboard accessible to both Idaho Power employees and contractors from
Idaho Power's website. The WMP details operational mitigation efforts when the FPI score is
red, including stopping planned work and changing distribution protection operations in certain
locations. A Red FPI score is a consideration in Idaho Power's determination of whether to
initiate a PSPS.
8.2. National Weather Service Red Flag Warning
A Red Flag Warning (RFW) is a forecast warning issued by the National Weather Service (NWS)
to inform the public, firefighters, and land management agencies that conditions are ideal for
wildland fire combustion and rapid spread. RFWs are often preceded by a Fire Weather Watch
(FWW), which indicates weather conditions that could occur in the next 12 to 72 hours.
The NWS has developed different zones across the nation for providing weather alerts (such as
RFWs) to more discrete areas. These zones are shown on this NWS webpage: Fire Weather.
RFWs for Idaho Power's service area include Idaho zones (IDZ) 401, 402, 403, 413, 420 and 422;
and Oregon zones (OR) 636, 637, 642, 634, 644, 645 and 646; and are monitored and factored
into Idaho Power's determination of whether to initiate a PSPS. Boise and Pocatello NWS
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
offices will not issue RFWs if fuels are moist and fire risk is low. The following thresholds are
used by most NWS offices:
Daytime:
• Relative humidity of 25% or less
• Sustained winds greater than or equal to 10 miles per hour (mph) with gusts greater
than or equal to 20 mph over a four-hour period
Nighttime:
• Relative humidity of 35% or less
• Sustained winds greater than or equal to 15 mph with gusts greater than or equal to
25 mph over a three-hour period
Lightning:
• The NWS rarely issues RFWs for lightning in the western U.S. For this to occur,
the Lightning Activity Level—a measure of lightning potential specifically as it relates to
wildfire risk—needs to be at 3 or higher.
8.3. NWS Fire Weather Forecasts
The NWS provides detailed forecasts for the different weather zones with an emphasis on fire
weather indicators (wind speed, relative humidity, lightning potential). A discussion
summarizing the weather patterns and highlighting fire threats is included in their
extended forecast.
8.4. Publicly Available Weather Models
Idaho Power's Atmospheric Science department uses the following weather models to predict
weather timing, duration, and intensity:
• Pivotal Weather Link (pivotalweather.com/model.php): Provides numerical weather
data, including a NWS blend of models, European Centre for Medium-Range Weather
Forecasts (ECMWF), United Kingdom Meteorological Office weather service
information, and GOES-16 satellite information.
• Graphical Weather Link (graphical.weather.gov/sectors/conusFireWeek.php): An NWS
website providing weather, water and climate data, forecasts, and warnings for the
United States for the protection of life and property. The Fire Weather page provides a
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
daily and weekly view of multiple weather and environmental conditions influencing
wildfire activity.
8.5. Idaho Power Weather Model
Idaho Power maintains its own Weather Research and Forecasting (WRF) model using
high-resolution data from Idaho Power's weather stations across its service area. This model,
along with publicly available weather models, helps develop weather forecasts that include
timing, duration, and intensity of weather systems. An Idaho regional WRF low-resolution map
view is available to the public at atmo.boisestate.edu/view/.
8.6. Storm Prediction Center Fire Weather Outlooks
The Storm Prediction Center's Fire Weather Outlook provides a current, one-day-ahead and
three-to eight-day forecast for wildfires over the contiguous U.S. This forecast accounts for
pre-existing fuel conditions combined with predicted weather conditions that result in a
significant risk of wildfire ignition or spread.
8.7. Current Weather Observations
Monitoring real-time weather conditions is important for determining whether the associated
risks warrant the need for a PSPS event. Resources available for observing current weather
conditions include direct, real-time data from Idaho Power's network of weather stations as
well as Remote Automatic Weather Stations, Windy: Wind Map and Weather Forecast, and the
National Weather Service National Oceanic and Atmospheric Administration's (NOAA) Weather
and Hazards Viewer.
Additionally, Idaho Power's PSPS program includes employees acting as field observers to
report on site conditions, detailed in section 8.14.
8.8. National Significant Wildland Fire Potential Forecast Outlook
The National Significant Wildland Fire Potential Forecast Outlook provides wildland fire
expectations for the current month, the following month, and a seasonal look at the two
months beyond that. The main objective of this tool is to provide information to fire
management decision-makers for proactive wildland fire management, reducing firefighting
costs, and improving firefighting efficiency.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
8.9. GBCC Morning Briefing
The Great Basin Coordination Center (GBCC) is the focal point for coordinating the mobilization
of resources for wildland fire and other incidents throughout the Great Basin geographic area,
which encompasses Utah, Nevada, Idaho south of the Salmon River, the western Wyoming
mountains, and the Arizona Strip. The GBCC hosts a morning briefing during fire season that
provides situational awareness for Idaho Power's service area.
8.10. GBCC Current and Predicted ERC and F1OO
The GBCC as described above also provides day-ahead Energy Release Component (ERC),
100-Hour Fuel Moisture (F100) and other fuel conditions information that helps Idaho Power
understand wildfire potential in the service area.
8.11. Fire Agency Input
Idaho Power works with Boise NWS fire forecasters through daily briefings and National
Interagency Fire Center (NIFC) Predictive Service forecasters on an as-needed basis,
generally regarding data clarification, to streamline the transfer of data, information,
and communications about wildland fires that may impact Idaho Power's service area.
Idaho Power works with other agencies, including the U.S. Bureau of Land Management (BLM)
and U.S. Forest Service, as wildland fires approach and impact Idaho Power T&D facilities.
8.12. De-Energization Windspeed Considerations
Idaho Power's service area covers 24,000 square miles across southern Idaho and eastern
Oregon. The environmental factors across this area vary drastically from high desert
landscape to mountainous terrain. Weather and environmental conditions also vary greatly
within this area. Regional vegetation becomes "conditioned" to withstand different
environmental conditions, which also influences de-energization thresholds. To account for the
impact these variations have on fire risk generated by weather conditions, Idaho Power has
developed regional windspeed considerations, which it will continue to refine with additional
data and weather technology.
8.13. Alternative Protective Measures
Considering the significant potential impact of a PSPS to customers, prior to implementing a
PSPS, Idaho Power thoroughly evaluates other potential alternative protective measures for
operating its T&D system both during fire season and in the context of a potential PSPS event.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
8.14. Real-time Field Observations
Idaho Power may deploy trained field observers to certain potential PSPS locations prior
to de-energization to evaluate and report on weather and circuit conditions on-site.
Field observers are equipped with mobile weather kits that include wind meters,
compasses, and communication devices to report real-time conditions. Information is
communicated to the PSPS Assessment Team for consideration during a PSPS event.
8.15. Other
As further described in the WMP, Idaho Power continues to evaluate expansion of its weather
forecasting tools and enhance the company's capability to detect and respond to fires with
wildfire detection camera systems.
9. Responsibilities
Implementation of the PSPS Plan involves various groups throughout the company. Below is a
non-exhaustive list of responsibilities by department, representatives of which will work
together to promote organized, consistent, and safe implementation of PSPS events. Idaho
Power reserves the right, at its discretion, to adjust roles, personnel, and responsibilities as
circumstances warrant.
9.1. Load Serving Operations
• Develop and implement safe and reliable power shutoff protocols and procedures.
• Ensure System and Regional Dispatch employees are appropriately trained to perform
relevant responsibilities under this PSPS Plan, and that such employees receive timely
information regarding wildfire risk and weather conditions for purposes of performing those
responsibilities during a PSPS event.
• Assist with PSPS evaluation and decision-making.
• Safely restore service to PSPS areas when notified by the acting incident commander.
• Participate in After-Action Reviews (AAR) (further discussed in Section 13) and ensure
modifications to PSPS protocol are implemented, as necessary.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
9.2. Atmospheric Science
• Monitor daily, weekly, and long-term weather forecasts.
• Monitor fuels conditions and trends.
• Monitor FWWs, RFWs, and High Wind Watches and Warnings.
• Communicate with external agencies for increased situational and conditional awareness.
Increase communications as conditions or circumstances require.
• Communicate internally to Idaho Power's Transmission & Distribution Engineering and
Reliability (TDER) department when conditions or circumstances indicate a PSPS may
be necessary.
• Support PSPS activities such as planning, training, and exercises prior to and during
fire season.
• Assist in PSPS information-gathering, evaluation, and decision-making during a PSPS event.
• Participate in AARs and ensure modifications to PSPS protocol are implemented,
as necessary.
9.3. Transmission and Distribution Engineering and Reliability
• Oversee wildfire mitigation program and support cross-departmental collaboration.
• Develop and implement safe and reliable power shutoff protocols and procedures.
• Act as incident command (IC) for PSPS events.
• Activate PSPS Assessment Team as needed.
• Ensure PSPS activities, such as operations planning, training, and exercises occur annually.
• Coordinate with Atmospheric Science to continue evaluating enhancements to situational
awareness capabilities.
• Support Dispatch and Customer Operations in developing de-energization and
re-energization plans for PSPS events.
• Support rapid repairs of damaged infrastructure as needed.
• Support Load Serving Operations in planning improvements to PSPS operational capabilities.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
• Following de-energization, and when it is safe to do so, coordinate with the
Vegetation Management Program (VMP) to begin removal of vegetation debris necessary
for re-energization.
• Use reasonable efforts to ensure contract resources are available and prepared for
PSPS events.
• Participate in AARs and ensure modifications to PSPS protocol are implemented,
as necessary.
9.4. Customer Operations Support and Regional Operations
• Ensure field personnel are appropriately trained to perform all relevant responsibilities
under this PSPS Plan.
• Develop and lead training modules for PSPS implementation (Customer Operations only).
• Communicate with Oregon and Idaho ESF-12.
• Assist with incident command (Customer Operations only).
• Assist in PSPS information-gathering, evaluation, and decision-making.
• Ensure crews and equipment are available to support PSPS events.
• Perform field observations, line patrols, and other PSPS tasks, as necessary.
• Perform required repairs to safely re-energize the system after a PSPS event.
• Request/obtain air patrol contractors for line inspections as required following a
PSPS event.
• Participate, with assistance from Corporate Communications, in Idaho Power's general
external education campaign.
• Ensure a coordinated and cohesive external and internal communication and notification
plan is in place and reviewed annually.
• During PSPS phases, collect and maintain Regional Dispatch Operations logs and other
incident information for reporting purposes.
• Develop, with assistance from Corporate Communications, a cohesive notification
framework with public safety partners, and consistently evaluate ways to increase
communication and outreach effectiveness.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
• Engage with public safety partners and critical facilities before, during, and after a
PSPS event.
• Coordinate with emergency managers to deploy community resource centers, as necessary.
• Lead AARs and ensure modifications to PSPS protocol are implemented, as necessary.
9.5. Substation Operations
• Monitor substations and perform actions to support PSPS operations as required.
• Coordinate activities with Dispatch and Customer Operations.
• Participate in AARs and ensure modifications to PSPS protocol are implemented,
as necessary.
9.6. Corporate Communications
Corporate Communications develops and executes PSPS communications to Idaho Power
customers and employees and supports other business units in their communication efforts
with regulators, critical facility operators, public safety partners, and other stakeholders.
Corporate Communications will:
• Work with public safety partners, critical facilities, regulators, and other stakeholders (in
coordination with Customer Operations and Regulatory Affairs) to develop a
comprehensive, coordinated, and cohesive customer notification framework.
• Develop and implement—with input from public safety partners—a wildfire education
and awareness campaign focused on wildfire prevention and mitigation, PSPS
awareness, and outage preparedness for customers.
• In the event of a PSPS:
• To the extent possible and in coordination with Customer Service and Information
Technology (IT), notify customers before, during, and after a PSPS event with the
following information:
• Expected timing and duration of the PSPS event
• 24-hour contact information and website resources
• Provide up-to-date information on a dedicated Idaho Power PSPS webpage
prominently linked on the Idaho Power homepage.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
• Distribute information via media and social media channels.
• Participate in AARs and modify communication practices, as necessary.
9.7. Safety
• Ensure safety professionals are appropriately trained to perform all relevant responsibilities
as needed under the PSPS Plan.
• Provide training on the PSPS Plan requirements for field personnel.
• Participate in AARs and modify communication practices, as necessary.
9.8. Customer Service
• Respond to customer calls and questions about a PSPS event with information provided by
Corporate Communications or the IC.
• Ensure customer service representatives are trained to manage customer interactions
during a PSPS event.
10. PSPS Operations
10.1. Preparedness
PSPS preparedness is a continuous effort involving Idaho Power, public safety partners,
state and local governments, communities, and customers. The TDER department coordinates
and facilitates activities of Idaho Power business units for wildfire prevention and mitigation
activities, while Customer Operations and Corporate Communications facilitate public outreach
and coordination efforts with external stakeholders. Figure 1 shows the PSPS
preparedness cycle.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
Figure 1
PSPS preparedness cycle
Idaho Power's goal is to take a community approach to wildfire preparedness by educating and
encouraging individual preparedness and relying on existing protocols and procedures currently
available through local governments and emergency response professionals. Idaho Power uses
metrics and monitoring of certain communication activities to evaluate the effectiveness of
outreach efforts and adjusts as needed based on feedback from customers and public
safety partners.
10.1.1. Community Preparedness
Idaho Power communicates with customers and public safety partners before and throughout
wildfire season through a variety of platforms to inform them of steps the company is taking to
reduce wildfire risk and ways they can help prevent wildfires and prepare for outages.
Communication themes include the following:
• What is a PSPS?: Explanation of PSPS events, including a map customers can use to
determine if their homes or businesses are in either a Tier 3 or Tier 2 risk zone.
• Be Prepared for Wildfire Season and PSPS events: Preparation tips like building an
outage kit and planning for feeding livestock, etc.
• Protecting the Grid: Measures Idaho Power is taking to enhance grid resiliency and
reduce wildfire risk.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
• How You Can Reduce Wildfire Risk: Tips for preventing wildfires when camping,
using fireworks, hauling trailers, etc.
• PSPS Event Information: Real-time information on active PSPS events, estimated shutoff
time, outage duration, and customers impacted.
10.1.2. Training and Exercises
Idaho Power coordinates and participates in tabletop exercises with public safety partners at
reasonable intervals to enhance knowledge of each other's emergency operations and ensure
smooth interactions during PSPS events.
10.2. Wildfire Season Operations
As described here and in Idaho Power's WMP, normal operations during wildfire season differ
from normal operations during the rest of the year based on heightened requirements
specifically targeted at forecasting and reducing wildfire risk.
10.2.1. Situational Awareness Activities
During wildfire season, Idaho Power closely monitors fire conditions and weather patterns.
Idaho Power's Atmospheric Science team prepares a monthly "Seasonal Wildfire Outlook"
report beginning in April and continuing through wildfire season containing information on
regional drought conditions obtained from the National Drought Monitor, weather and climate
outlook, seasonal precipitation, and temperature outlooks from NOAA, the NWS, and a regional
wildfire outlook.
During wildfire season, the Atmospheric Science team will determine a daily FPI as described in
Section 5.2 of the WMP describing shorter-term weather and fire conditions specific to wildfire
risk zones across Idaho Power's service area.
10.2.2. Key Grid Interdependent Utilities and Agencies
Idaho Power exchanges dispatch information with key grid interdependent utilities and energy
providers to expedite communication and coordination during wildfire events. These contacts
include Avista, Bonneville Power Administration, Northwestern Energy, NVEnergy, Oregon Trail
Electric Cooperative, PacifiCorp, Raft River Electric, Seattle City Light, and the U.S. Bureau of
Reclamation. Idaho Power also exchanges dispatch information with NIFC, BLM Fire Dispatch,
and various National Forest Service district offices—including Idaho Power dispatch receiving
BLM and U.S. Forest Service incident command information during wildfire events—to improve
communication and coordinate fire-related activities.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
10.3. Proactive Communications
Although the size of Idaho Power's service area, geographic and environmental diversity,
and unpredictable nature of Idaho and Oregon weather make it challenging, Idaho Power is
committed to providing as much advance notice as reasonably possible in preparation for a
PSPS event. Figure 2 provides the communication timeline Idaho Power utilizes, to the extent
possible, for PSPS events, including notifications to public safety partners,
circumstances permitting.
10.3.1. Notifications and Emergency Alerts
Consistent with Oregon Division 300 Administrative Rules and Emergency Support Function-12,
Idaho Power coordinates with public safety partners in advance of a PSPS event to prepare
information needed by these partners and establish communication protocols for critical
decision-making before and during a PSPS event, including restoration activities.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
Event Timing Description of Planned Communications
Preliminary 48-72 hours in advance of a potential PSPS event,priority notification
Notifications to Public Safety Partners and operators of critical facilities.
PSPS 24-48 hours in advance of an anticipated PSPS event,secondary
notification Public Safety Partners,operators of critical facilities and initial
Watch notification to affected customers within the PSPS event boundary.
PSPS 1-4 hours in advance of an imminent PSPS event, if possible, notification
Warning to Public Safety Partners,operators of critical facilities and all affected
customers within the PSPS event boundary.
PSPS Upon initiating a PSPS, if possible, notification to Public Safety Partners,
operators of critical facilities and all customers within the PSPS event
Alert boundary and at a minimum,with status updates at 24-hour intervals
until restoration begins for PSPS events lasting longer than 24 hours.
MMMMMMMI
When re-energization begins, if possible, notification to Public Safety
Update Partners,operators of critical facilities and all affected customers within
the PSPS event boundary.
Final Once re-energization is complete, Idaho Power will attempt to provide
notice to Public Safety Partners,operators of critical facilities and all
Update affected customers within the PSPS event boundary.
Figure 2
Possible PSPS event communication timeline
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
10.4. PSPS Phases
10.4.1. Phase 1 & PSPS Assessment Team Activation
The decision to implement a PSPS event will be based on the best available data for weather
and other fire-related conditions as detailed above in Section 8—PSPS Implementation
Considerations. Multiple events may require simultaneous management of other
storm-related outages or other PSPS events.
Idaho Power will transition from normal wildfire season operations to Phase 1 of a PSPS event
at the direction of the Wildfire Mitigation and T&D Engineering director or designee.
During Phase 1, Idaho Power will activate the PSPS Assessment Team, which includes
representation from a minimum of the departments identified in Section 9. The Wildfire
Mitigation and T&D Engineering director or designee will establish an incident commander for
the event to lead the PSPS Assessment Team during the phases of the PSPS event. The PSPS
Assessment Team will hold meetings and/or conference calls (collectively referred to as
meetings) as needed to discuss current and forecasted weather conditions and other
information regarding a potential PSPS event. The IC will facilitate PSPS Assessment Team
meetings and the PSPS Assessment Team will be responsible for recommending maintaining
Phase 1, escalating to Phase 2, or de-escalating to normal operations. The PSPS Assessment
Team will also recommend issuance of preliminary notifications of a potential PSPS event to
customers, public safety partners, critical facilities operators, and ESF-12 leads consistent with
Oregon Division 300 Administrative Rules and Emergency Support Function-12.
During Phase 1, the PSPS Assessment Team will review the PSPS Plan and supporting
documents. The team will perform an operational risk assessment to develop a
recommendation for PSPS escalation. The ultimate determination on whether to escalate to
Phase 2 is made by the IC. As soon as reasonably practicable following a Phase 2 notification,
the full PSPS Assessment Team will be placed on standby, and team member availability will be
determined. In addition, the vice president (VP) of Planning, Engineering, and Construction
(PEC), the Customer Operations VP, and chief operations officer (COO) or their designees will be
placed on standby for decision making purposes.
10.4.1.1. Phase 1 Notifications
Depending on the timing and specific circumstances of the PSPS event, public safety partners
and critical facility operators may be notified during this phase. These notifications may include
emails, text messages, and/or phone calls as determined by the PSPS Assessment Team in
coordination with Corporate Communications.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
10.4.2. Phase 2
Phase 2 actions are determined by additional situational awareness activities and timing of
forecasted weather events. Upon transitioning to Phase 2, Idaho Power will provide external
notifications as detailed in Figure 2, as determined by the PSPS Assessment Team in
coordination with Corporate Communications.
10.4.2.1. Regional Event Operations and Coordination
In collaboration with the PSPS Assessment Team, Idaho Power regional leadership will establish
a regional event coordinator. The event coordinator's main role is to coordinate activities
across the region associated with the PSPS event and restoration of electric service, as needed,
following a PSPS event.
Regional Operations personnel have developed action plans and switching orders as part of
their preparedness activities. These plans and switching orders will be reviewed and refined as
necessary based on the current and forecasted conditions and will include situation-specific
tactics and detailed instructions.
10.4.2.2. Conduct Operational Risk Analysis
The PSPS Assessment Team will present its operational risk analysis recommendation to the VP
of Planning, Engineering and Construction (PEC), VP of Customer Operations, and/or the COO
or their designees, who will then evaluate the PSPS Assessment Team's recommendation for
final determination. However, all three positions may not be available during an event. In this
case, any one of the three positions (i.e., the VP of PEC, VP of Customer Operations, or COO)
have the authority to make a final determination of whether to proceed to Phase 3
implementation of a PSPS event based on the PSPS Assessment Team recommendation.
10.4.2.3. Request to Delay a PSPS Event
There may be requests to delay proactive de-energization from the public safety partners or
ESF-12. This may occur for several reasons, with the most anticipated being an impact to a
customer's or fire response agency's ability to pump water for fire suppression during the
outage. Delay requests may be routed through dispatch and will be sent to the PSPS
Assessment Team for evaluation. The PSPS Assessment Team will provide the VP of PEC, VP of
Customer Operations, and/or the COO (or designee) a recommendation on whether to approve
the proactive de-energization delay. The decision will be made by the VP of PEC, VP of
Customer Operations, and/or the COO (or designee). As soon as practicable after receiving the
request, Idaho Power will notify the ESF-12 liaison of the delay request and basis of such
request, as well as the final determination and the underlying justification.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
10.4.2.4. Field Observations and Response Teams
TDER and Regional Operations will coordinate field personnel to be mobilized and dispatched
to strategic locations, including areas with limited weather and system condition visibility,
to perform field observations for on-the-ground, real-time information critical to inform
decisions on proactive de-energization. Field observations include—without limitation—
conditional assessments of system impacts from wind and vegetation, flying debris,
and slapping conductors.
10.4.2.5. Customer and Community Notifications
Depending on the timing and specific circumstances of the PSPS event, Idaho Power may use
various forms of communication (including media outreach) to provide information and
updates to public safety partners, critical facility operators, and customers—particularly those
impacted by the PSPS event. Information and updates will include the reason for the
potential de-energization, where to find real-time updates on outage status, and other relevant
safety and resources.
10.4.3. Phase 3
Upon determination to proactively de-energize, the Load Serving Operations (LSO)
representative of the PSPS Assessment Team will inform System and Regional Dispatch
Operations and request coordination of the estimated time to begin the PSPS. The regional
manager, or their assigned representative in the region where the PSPS will take place,
will coordinate with the event coordinator to pre-position field personnel where manual
de-energization is required and to stand by for orders to de-energize. System and Regional
Dispatch Operations will implement the PSPS according to their established processes.
10.4.3.1. Customer and Community Notification
Idaho Power will use various forms of communication (including media outreach) to provide
information and updates to customers and other stakeholders, particularly those impacted by
the PSPS event. Information and updates will include the reason for the de-energization,
where to find real-time updates on outage status, and other relevant safety and resource
information regarding the PSPS.
10.4.4. Phase 4
10.4.4.1. System Inspections
When it is safe to do so, Idaho Power will begin line patrolling activities to inspect T&D circuits
and other potentially impacted Idaho Power facilities prior to re-energization. Patrol personnel
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
will report system conditions back to System and Regional Dispatch Operations for coordination
with field crews. Patrols will be performed to ensure conditions and equipment are safe to re-
energize.
10.4.4.2. Repair and Recovery
Line crews will repair T&D facilities as coordinated with System and Regional Dispatch
Operations, replacing damaged equipment and performing other actions to support safe
re-energization of the T&D system.
10.4.4.3. Incident Management Support
The PSPS Assessment Team will continue to monitor fire and weather conditions throughout
the event. Logistics and mutual assistance requirements will be determined and acted upon per
existing internal plans and processes. If re-energization will be delayed longer than anticipated
due to the magnitude of the event, the Emergency Management Team (EMT) will be utilized for
additional support.
10.4.4.4. Communicate PSPS Event Conclusion
Idaho Power will use various forms of communication (including media outreach) to inform
customers and other stakeholders, particularly those impacted by the PSPS event, when repairs
are complete, and it is safe to re-energize the system. This may occur in stages as different
feeders or feeder sections are repaired and safe to re-energize. The outage map on Idaho
Power's website will be updated during the event. Idaho Power will also leverage existing public
agency outreach and notification systems as done at other points in the PSPS process.
10.4.4.5. Re-energization
Once re-energization activities are completed and service is restored, crews and support staff
will demobilize and return to normal wildfire season operations as described in the WMP.
10.4.5. Post-incident Review
During PSPS phases, the Customer Operations lead will collect and maintain Regional Dispatch
Operations logs and other incident information required for reporting purposes.
Following conclusion of a PSPS event, the Customer Operations lead, or their designee will
conduct informal, high-level debriefs to identify potential modifications to PSPS protocol based
on lessons learned during the event. The assigned representative will consolidate the feedback
and file as part of the incident documentation.
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Idaho Power Company Wildfire Public Safety Power Shutoff Plan
Also following the PSPS event, the IC will conduct an AAR with the PSPS Assessment Team to
identify potential modifications to PSPS protocol based on lessons learned during the event.
The IC will consolidate the feedback and provide it to the Customer Operations lead.
After wildfire season, the Customer Operations lead may conduct an AAR focusing
on operational processes, communications, customer support, as well as emergency response
and restoration. Idaho Power may also request feedback from external stakeholders on
coordination efforts, communications, and outreach effectiveness for integration into the
AAR report.
11. Financial Administration
Idaho Power will track expenses related to PSPS events for Public Utility Commission of Oregon
(OPUC) and Idaho Public Utilities Commission (IPUC) reporting and potential recovery of
expenses through regulatory processes. Expenses will be tracked for the entire PSPS event
(Phase 1 through conclusion of the Post-Incident Review and filing the PSPS event report with
the OPUC) to include, without limitation, time reporting, equipment, and any supplies used to
set up customer resource centers and provided to customers (e.g., water, ice, etc.).
12. Reporting
Employees are required to manage information regarding PSPS events pursuant to Idaho
Power's Information Retention Policy and underlying standards. Idaho Power will submit
reports to the IPUC and OPUC as required.
13. After-Action Report
An AAR is a structured review or de-brief process used to evaluate the effectiveness of the Plan
and potential areas for improvement. This process may be performed after a PSPS event and
may be confidential at the direction of Idaho Power's general counsel or designee.
14. Training
Idaho Power will provide annual training, prior to or shortly after the beginning of wildfire
season, to relevant employees on their respective roles in performing this PSPS Plan.
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Wildfire Public Safety Power Shutoff Plan Idaho Power Company
15. Exercises
Idaho Power will exercise this PSPS Plan on an annual basis prior to wildfire season using
various scenarios and testing all or any portion(s) of the Plan which may include:
• Testing text and/or phone alerts with a test group of public safety partners
• Testing tactical operational plans, such as reporting field observations or
positioning employees at manually operated disconnects to test timing for
de-energization and field inspections of T&D assets
• Discussing and/or practicing roles and responsibilities of both strategic and tactical
operations, including decision-making handoffs and hypothetical scenarios
• Discussing and/or developing re-energization plans
• Testing capacity limits on incoming and outgoing communications systems

Idaho Power Company Oregon Wildfire Requirements and Recommendations
Appendix C
Wildfire risk zone map book
Appendices

N IDAHo POWER,
Wildfire Risk Zone Map Book

Idaho Power Wildfire Risk Zone Map Book
List of Figures
Figure 1
Canyon Region—Tier 2 zones.....................................................................................................1
Figure 2
CapitalRegion—Boise south........................................................................................................2
Figure 3
CapitalRegion—Boise Front ........................................................................................................3
Figure 4
CapitalRegion—Centerville .........................................................................................................4
Figure 5
Capital Region—Mountain Home area ........................................................................................S
Figure 6
CapitalRegion—Idaho City ..........................................................................................................6
Figure 7
Eastern Region—American Falls.................................................................................................7
Figure 8
Eastern Region—Pocatello south.................................................................................................8
Figure 9
Eastern Region—Pocatello area...................................................................................................9
Figure 10
Eastern Region—Salmon area....................................................................................................10
Figure 11
Out of territory—Austin Junction, Oregon...............................................................................11
Figure 12
Out of territory—Tollgate, Oregon...........................................................................................12
Figure 13
Out of territory—Clark County, Idaho......................................................................................13
Figure 14
Out of territory—Elko County, Nevada ....................................................................................14
Figure 15
Southern Region—Pine/Featherville area................................................................................15
Figure 16
Southern Region—Rock Creek, Twin Falls south ......................................................................16
Page i

Wildfire Risk Zone Map Book Idaho Power Company
Figure 17
Southern Region—Twin Falls/Buhl...........................................................................................17
Figure 18
Southern Region—Wood River Valley......................................................................................18
Figure 19
WesternRegion—Ola...............................................................................................................19
Figure 20
Western Region—Cascade/Donnelly .......................................................................................20
Figure 21
Western Region—Council area ................................................................................................21
Figure 22
Western Region—Emmett/Horseshoe Bend............................................................................22
Figure 23
Western Region—Garden Valley/Crouch.................................................................................23
Figure 24
Western Region—Halfway, Oregon .........................................................................................24
Figure 25
Western Region—Jordan Valley, Oregon .................................................................................25
Figure 26
Western Region—Juntura, Oregon ..........................................................................................26
Figure 27
Western Region—Lowman.......................................................................................................27
Figure 28
Western Region—McCall/New Meadows................................................................................28
Figure 29
Western Region—Riggins south...............................................................................................29
Figure 30
Western Region—Smiths Ferry................................................................................................30
Figure 31
WesternRegion—Unity, Oregon..............................................................................................31
Figure 32
Western Region—Yellow Pine..................................................................................................32
Figure 33
Western Region—Weiser, Payette, Vale Tier 2 zones..............................................................33
Page ii

Idaho Power Wildfire Risk Zone Map Book
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' e 1
- � iesne car
rl
taof tail
Jordan VAW' x
i ��PVYY6t,
Q Tier 3 Risk Areas Tier 2 Risk Areas:
0 Tiier2 Risk Areas Idaho Power Wildfire Risk Area Detail CP2T10;CP2T11;
City Boundaries CP2T32;CP2T6;CP2T8;
BLM Capital Region - Boise South CP2T9
State Tier 3 Risk Areaa
�BOR � [` 7.5 5 CP3T4;CP3T5
CUles
Figure 2
Capital Region—Boise south
Page 2

Idaho Power Wildfire Risk Zone Map Book
Hidden Spring
L,glc
Garden City
_ 5_5
1 - Star \
-- -- `t�s
P W Fairview Ave
Boise
Meridian
r _
0Eau © w o—land Rd
D J
C a cry
j�O
a
y Rd
i I � •Ca+ncA .
1 � •G�uadc
1Veiser Stanlr!y u
Vale �
ft Aieaef Detail Idaho Gty - - -
iCaldwel
lercLw Valle'/, 11,.1 M
Ifth—POWER
� Twin Fa".•..
Tier 3 Risk Areas
Tier 2 Risk Areas:
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail CP2TI;CP2T31;
City Boundaries CP2T12;CP2T6
DOD/Coe Capital Region - Boise Front
BLM Tier 3 Risk Areas:
State CP3T1;CP3T2;CP3T3;
USFS 0 7.5 5 CP3T4;CP3TS;CP3T7;
BOR Miles CP3T8
Figure 3
Capital Region—Boise Front
Page 3

Wildfire Risk Zone Map Book Idaho Power
Grimes 1 sss
er ille
mite
ente rv,l'e
New
^tervill�
itaMway McCal
-- .� Courcil
J^fYeasv ` }r� gam.
Ana DMN J �_ io Ci
Vale f
'r caw�ta ��c�
�rt
xrdr,� � �hburon twm�
V.Uyi=Tier 3 Risk Areas
Tier 2 Risk Areas:
o Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail w2T17
City Boundaries
BLM Capital Region - Centerville Tier 3Risk Areas:
CP3T10;CP3T11;CP3T9
State
USFS 0 7.5 5 �IDAM
BOR Miles PWVER
Figure 4
Capital Region—Centerville
Page 4

Idaho Power Wildfire Risk Zone Map Book
■
J
h.L ■ `�
`
■ e
NO—
R,,
t Prey
vazmn Mount
167
167
1 1
all ■
i
StnNey
oN
�caia e' ease". Ke«,—
I O,�r+an tbn�/
vaiiw
a•f or o.raii
I Twn ralh.-
I
—L-----------
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail Tier Risk Areas:
City Boundaries CP2T1;CP2T16,,CP2T2;CP2T3;
DOD/COE Capital Region-Mountain Home Area CP2T4;CP2T5
BLM
State
USFS
0 2.5 5 10
BOR A Miles VAW�„
Figure 5
Capital Region—Mountain Home area
Page 5

Wildfire Risk Zone Map Book Idaho Power
.o c
r
Vale,
R+Y
KeWu R
1Caldwdl�
m Tier 3 Risk Areas
Tier 3 Risk Areas:
o Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail
CP3T10;CP3T3;CP3T4.
City Boundaries CP3T5;CP3T6;CP3T'
000/Coe Capital Region - Idaho City CP3TS;CP3T9
BLM
State r•—
USFS 0 2.5 5 �1y
L BOR Miles
Figure 6
Capital Region—Idaho City

Idaho Power Wildfire Risk Zone Map Book
Ab„r�n�r,
- --------------- �_l�y
Fairvie 1
American Falls
J
POWER
J
•Ketchum Mm Q
Idaho Falls I 37
'Blackfoot 1
Amer — Pocata•Ib - {
F h
�,'— �• Soda/ Sprtgs
•Twin Ana of U.t•iL
Falls CJ I
v �
I I
O Tier 2 Risk Areas Tier 2 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail E2T2;E2TS
BLr1 Eastern Region-American Falls
State
Tribal MAW
BOR A 0 2.5 5 10 I`IPOMR
Miles
Figure 7
Eastern Region—American Falls

Wildfire Risk Zone Map Book Idaho Power
LBlackrock
Portne.`
0
0
00
0
lrtdlan C
taa�
CD
Ind. Rock,
?irk bad
Yob
Oo
Creek
_i �IOaAo Fa
Twomilo Craak
'Blackfoot
Amn+can Pocatdb :30
��_{J7 falls ' Sod.>.Spapall Dry Cenyon eek
Y �•Araa of Data4 . Harkness 6r
I-j
I
C7 Tier 3 Risk Areas Tier 2 Risk Areas:
o Tier z Risk Areas Idaho Power Wildfire Risk Area Detail
E2T1;E2T3;E2T4:E2T6:
City Boundaries EM
Eastern Region Pocatello S
BLM
State
USFS p 2 5 5 �Q-IDAHO
Figure 8
Eastern Region—Pocatello south
Page 8

Idaho Power Wildfire Risk Zone Map Book
Chubbuck
Don
`'10
Pocatello
13
Blackrock
a Portne.4
Z
am
leano r.,�ls
C•
'&ackfoce
ATCfKa� -9prd(zilo
Fall.
Soda Spnngc
Area of Detail. ~\
B�reY c
Tier 2 Risk Areas:
Q Tier 3 Risk Areas Idaho Power Wildfire Risk Area Detail E2T3;E2T6;E2T7;E2T8
C-3 Tier 2 Risk Areas Eastern Region - Pocatello Area Tier 3 Risk Areas:
City Boundaries E3T1; E3T2; E3T3; E3T4; E3TS:
BLM E3T6;E3T7;E3T8
State
�pw A �o
Tribal Miles W r"Mir-
USFS
Figure 9
Eastern Region—Pocatello area
Page 9

Wildfire Risk Zone Map Book Idaho Power
z
30
ro9yo929
Salmo i
D
0
0
o
Are Dete _
POWER
Tier 2 Idaho Power Wildfire Risk Area Detail E2T1O; sk Areas:
� Tier 3 Risk Areas 2T10;E2T11;E2T12;E2T13;E2T14;
O Tier 2 Risk Areas Eastern Region - Salmon Area E2T15;E2T16;E2T17;E2T18;E2T19;
E2T20;E2T21;E2T22;E2T24;E2T26;
City Boundaries E2T27;E2T9
B1M
State Tier 3 Risk Areas:
USFS / 0 2.5 5 10 E3T10;E3T9
Miles
Figure 10
Eastern Region—Salmon area
Page 10

Idaho Power Wildfire Risk Zone Map Book
r,-
Prairie City
to Garde'
Hallway
1
aofDOW
Vak "
llurac� r
O Tier 2 Risk Areas
Tier 2 Risk Areas:
—1 City Boundaries Idaho Power Wildfire Risk Area Detail or2T3
B`M Out of Territory-Austin Junction, OR
State
USFS
A 1 n
HENIM
.
h1i es
Figure 11
Out of territory—Austin Junction, Oregon
Page 11

Wildfire Risk Zone Map Book Idaho Power
Bingham
Springs
�f
•frc
wra Walla
Troy �
i Flgin
� Rsar.
t to era de E to yr x•
naitwm %
i
C« ez
0 Tier 2 Risk Areas
Tier 2 Risk Areas'
Co Boundaries Idaho Power Wildfire Risk Area Detail OT2T4
BLM Out of Territory-Tollgate, OR
State
USES �'DA H 0
A 0 25 5 10 �251130WER
�o1des
Figure 12
Out of territory—Tollgate, Oregon
Page 12

,n Heel
i
y I Dubois
I ti
Area of Detail P
I.
` �Idafw Falls
B{adduet
p TW z PJSk Area
city Boundaries Idaho Power Wildfire Risk Area Detail Tier z R;4 A,--
OUT.
BLM Out of Service Territory-Clark County, ID
State
USFS /�IDAM
A o 5 5 ,o INPO�N�.
Miles
Figure 13
Out of territory—Clark County, Idaho
Page 13

Wildfire Risk Zone Map Book Idaho Power
lell<
I
1 ( i
Q �,er 2 Risk Areas
City Boundaries Idaho Power Wildfire Risk Area Detail Tier 2 R,sk Areas
BLM OUT I
Out of Service Territory- Elko County, NV
Tribal
USFS
A 0 2.5 5 10POwel
Miles
Figure 14
Out of territory—Elko County, Nevada
Page 14

Idaho Power Wildfire Risk Zone Map Book
F.•atl illy
r'
r
P
cascade
v�ser .sta'+kv
• 1
Wd Cay ./
,,�`, Ketchum
1 k �
Madan Va1ry _..
Twin Falls -Z�.
O Tier 3 Risk Areas Tier 3 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail s3T1;53T2
BLM Southern Region - Pine Featherville Area
State
USFS
Pn4 0 2 5 5 10 IDAH0
`_POWER
Figure 15
Southern Region—Pine/Featherville area
PaL

Wildfire Risk Zone Map Book Idaho Power
MG 4r angh
Magic Valley
Regional r'
Airport Wf
Striker
z
w
0
0
0
m
Rock Creek
Artesian City
C
H--Nome
Ame.«a,
Fans
Twin =
v
Ana N Detail
I
I
I
Tier 2 Rid Arra•.
O Tier 2 Risk Areas S2T 1
City Boundaries Idaho Power Wildfire Risk Area Detail
DODICOE Southern Region - Rock Creek
BLM
State s"MiDAM
USES A D 2.5 5 10 POMR
PAdes
Figure 16
Southern Region—Rock Creek, Twin Falls south
Page 16

Idaho Power Wildfire Risk Zone Map Book
Eluhl `
o
Twin Fars
7M1
P�
-Ketchum �Arco
MOla1h111 Rome
American
Falls
T Fa4 17
6_1kv
Area o1 Deteil in
---------------
I
O Tler 2 Risk Areas Tier 2 Risk Areas:
City Boundaries S2T8,S2T9,S2T10
Idaho Power Wildfire Risk Area Detail
DOD/COE Southern Region-Twin Falls/Buhl
BLM
State EMIDAW
A 0 2.5 5 10 `_�mri
Miles
Figure 17
Southern Region—Twin Falls/Buhl
Pag.

Wildfire Risk Zone Map Book Idaho Power
r+�aey
ty
Jsr.*r 1
�rCity
Am
'A
Falls
Mountain Moms
Ameirsi�
Twin Falls+-}
Tier 2 Risk Areas:
d Tier 3 Risk Areas Idaho Power Wildfire Risk Area Detail S2T2;S2T3;s2T4;S2T5;52T6
O Tier 2 Risk Areas
City Boundaries Southern Region -Wood River Valley Tier 3 Risk Areas:
S3T3;S3T4;S3T5
BLM nnww��JA
State A 1 7.5 5 10 Ipm
USFs
Miles
Figure 18
Southern Region—Wood River Valley
Page 18

Idaho Power Wildfire Risk Zone Map Book
Gross
la
1
nairwav r r•Iccan
i wrrni
/ �scade
vale �4rea Of OsUi
Idab Gq
_-" 'CalAvell: Base
Fla,ntan rbmc
O Tier 2 Risk Areas
City Boundaries Idaho Power Wildfire Risk Area Detail W2T19 W2T21s:
W2T19;W2T21;W2T22;W2T24
BLM Western Region -Ola
State
USFS �IDAM
A D 25 .5 �pamm
Miles
Figure 19
Western Region—Ola
Page 19

Wildfire Risk Zone Map Book Idaho Power
Donnelly
m
f
Mi
�I� N
i�
Fntcrpise !�•R�ggns �
IlaHwaY•. f Tmccall
A
�k
,tire G
t i
• f C Katch,. i Cascade
Tier 2 Risk Areas:
Q Tier 3 Risk Areas W2T38
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail
City Boundaries Tier 3 Risk Areas:
BLM Western Region - Cascade/ Donnelly W3T3;W3T4;W3T`.-
W3T6;W3T7
State
USFS o 2.5 5 10 —��iDAHO
r 4 BOR Miles U~POMR
Figure 20
Western Region—Cascade/Donnelly
Page 20

Idaho Power Wildfire Risk Zone Map Book
tip CUCII
� J
Goodrich
Saco, Mesa
.�Ipine
Calnb clge
�'� Hi9MwaY 95
Indian Valley
P
T
e
EnfN '
la Grande pnw. � .R I9irz
Halfway prya of�ita'r`�all ,�°
7 I i
yQLredc
sta-dey
Yak
Idaho Gry
Base
(Caldwell
O Tier 2 Risk Areas Tier 2 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail W2T32;W2T33;W2T34;W2T35;
W2T36;W2T37
BLM
State Western Region -Council Area
USFS
BOR 0 2") 5 10 �1�10•
Miles _��m'
Figure 21
Western Region—Council area
Page 21

Wildfire Risk Zone Map Book Idaho Power
Brownlee
S -eat
1
Hors shoe
ett Bench
Emmett
YV av
t Ana of Detail
p
7--
Ida6o cm
o �
Tier 2 Risk Areas:
0 Tier 3 Risk Areas CP2T1S;W2T12;W2T33;
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail WHIS;W2T16;W2T3;
City Boundaries W2T6;W2T7;W2T8;W2T9
BLM Western Region - Emmett/ Horseshoe Bend Tier 3 Risk Areas:
State CP3T1;CP3T2
BOR h1iles MOVER
Figure 22
Western Region—Emmett/Horseshoe Bend
Page 22

Idaho Power Wildfire Risk Zone Map Book
Crouch
s
�Oe,,na�pd Garden Valley won r
Gr M�
rm�
a, o° OP
C«�1 4
Waea Area of Detail Seaier
I .caldwelY
I = Base'
I
C Tier 3 Risk Areas
Tier 2 Risk Areas.
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail W2T12
City Boundaries
eu� Western Region - Garden Valley/Crouch Tier 3 Risk Areas
W3T1
State
USFS U 25 5 I�W
BOR Miles POMR
Figure 23
Western Region—Garden Valley/Crouch
Pag

Wildfire Risk Zone Map Book Idaho Power
Carson
Jimtown
Sunset
tiff
Halfway
Pine
�,t gRall
Ana Of awtail Cciricil
J Cascade
I
Q Tier 3 Risk Areas
Tier 2 Risk Areas:
O Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail w2T3e
City Boundaries
BtM Western Region- Halfway, OR Tier 3Risk Areas:
W 3T]2
USFS
0 0.5 1 2 `1DAMO
i POMR
Figure 24
Western Region—Halfway, Oregon
Page 24

Idaho Power Wildfire Risk Zone Map Book
9
9:
O
z O
O =
(Y C)
O
vats r rAv
Base
Icaww..ii t'�
_ dada^
.1v
11 ,',IMNIM'
r
AnaiHl1 ta,I
I
Mount.un
0 Tier 2 Risk Areas
Tier 2 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail CN2T1;CN2T2
BLM Western Region -Jordan Valley, OR
State
0 5 1 o t de, `n 10AM0
POWEF:`
Figure 25
Western Region—Jordan Valley, Oregon

Wildfire Risk Zone Map Book Idaho Power
J Lint ura
V�Is
finis � Fal�.pi
Arw of D*W Q
/ lm bn Valley,
0 Tier 2 Risk Areas
Tier 2 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail w2T50
BLM Western Region -Juntura, OR
State
11
m r,a ies �PM1
Figure 26
Western Region—Juntura, Oregon
Page 26

Idaho Power Wildfire Risk Zone Map Book
Boise National
Fores[
.7n
J
.Cou+d
� Lleho GtY �•.
_rvell �, Ketch-
Tier 2 Risk Areas
Idaho Power Wildfire Risk Area Detail Tier2Risk Areas'
City Boundaries W2T52
State Western Region- Lowman
USFS
BOR
A 15 5 ,o �.
Miles
Figure 27
Western Region—Lowman

Wildfire Risk Zone Map Book Idaho Power
p
Nevs Mcadov.,
Meadows
Mccall
Lak, rk
•Try N •GraoMie
Eirterplae i •R-9g,-
� r
Ar..of D.tail
/ Halfway j�,McGn
,y 7 �1
W—
Vale R
• f Idaho Gty
O Tier 3 Risk Areas Tier 2 Risk Areas:
= Tier 2 Risk Areas Idaho Power Wildfire Risk Area Detail W2T38;W2T40;W2T43;
W2T45
City Boundaries Western Region- McCall/ New Meadows
BLNI Tier 3 Risk Areas:
State W3T10;W3T8;W3T9
USFS (i 2.5 5 10 ' p
BOR Mlles
Figure 28
Western Region—McCall/New Meadows
Page 28

Idaho Power Wildfire Risk Zone Map Book
Pollock
I' i,hurst
O
vs
Ot<<ry �\ Grenp-.i
5
Entcrp,Kc � �
'Area of Dauil
MalfwaY � i-'-}hkCdl
C � sound
Cascade
�. s^ W—,
Tier 2 Risk Areas Tier 2 Risk Areas:
_City Boundaries Idaho Power Wildfire Risk Area Detail w2T4e;w2T47
BLM Western Region- Riggins South
State
USFS
A 0 25 5 10 ONpoff
Miles
Figure 29
Western Region—Riggins south
Na

Wildfire Risk Zone Map Book Idaho Power
r
Cascade
Re
r ere
e e*
_ v
c�
L
Cabarton
J
A'>ha
55
WU,i
QwnN
' Smitl s Ferry
Weiser
A—of Dotail _
Idaho Gly
0 Tier 3 Risk Areas Tier 2 Risk Areas:
O Tier Risk Areas Idaho Power Wildfire Risk Area Detail W2T25;W2T26;W2731
City Boundaries Tier 3 Risk Areas:
BLM Western Region Smiths Ferry W3T11;W3T2;W3T4
State
USFS o 25 5 10
BOR Miles 1 .
Figure 30
Western Region—Smiths Ferry
Page 30

Idaho Power Wildfire Risk Zone Map Book
Tim
Fn`
S v�th
Pole C
E. vn
la Grand,
fd/itil
\�JJ Unity
An@ofDOW
r
ICakivel
1=Tier 2 Risk Areas
Tier 2 Risk Areas:
City Boundaries Idaho Power Wildfire Risk Area Detail w2T49
BLM Western Region - Unity, OR
USFS A
0 25 5 Milk
tildes .,...". ,.•,•
Figure 31
Western Region—Unity, Oregon
Page 31

Wildfire Risk Zone Map Book Idaho Power
11"Mpm
ptein
low Pi
I/ 0
p"
McCall
Counol A—fJD.tail
Cascade
SrarJ.y
O Tier 3 Risk Areas
Tier 2 Risk Areas:
O Tier Risk Areas Idaho Power Wildfire Risk Area Detail W2T42
City Boundaries
USFS Western Region-Yellow Pine Tier 3Risk Areas:
W3T13
0 0 5 2 �10Pi 0
99 POWER
Figure 32
Western Region—Yellow Pine
Page 32

Idaho Power Wildfire Risk Zone Map Book
ao
O
5
Onta o
`7
PAVETT
Vale
v
op
Ca...... ssa
at
,.
avab
WJq Crty W
Parma 0
�Gk6ell
oI
O Tier Z Risk AMW Tier 2 Risk Areas:
CN2T9;WTI;W2T10;W2T31;
GtvBoundaria Idaho Power Wildfire Risk Area Detail W2T14;W2T18;W2T2;W2T20;
DOE W2T23;W2T27;W2T28;W2129;
BLM Western Region -Weiser Payette Vale W2T30;W2T4;W2T5;W2T51
stow _
USFWS 0 2.5 5 1�
BOR A Miles QMPMMR
Figure 33
Western Region—Weiser, Payette, Vale Tier 2 zones

Oregon Wildfire Requirements and Recommendations Idaho Power Company
Appendix D
Oregon wildfire requirements and recommendations
Appendices

IDAHo POWER,
Oregon Requirements
and Recommendations

2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
Oregon Requirements and Recommendations
This appendix provides additional information specific to wildfire-related requirements, as well
as wildfire-related recommendations, in Oregon.
Oregon Administrative Rule (OAR) Regulatory Compliance Index
Below is a mapping of Wildfire Mitigation Plan rules to sections within Idaho Power's WMP.
Wildfire Protection Plan Filing Requirements—OAR 860-300-0020
Oregon Requirement—OAR .1 1 1 1 1 1 Corresponding Location in WIVIP
(1J Wildfire Mitigation Plans and Updates must,at a minimum,contain the See Section 3:Quantifying Wildland Fire Risk
following requirements as set forth in Section 3(2)(a)-(h),chapter 59Z
Oregon Laws 2021 and as supplemented below: See Idaho Power website and Appendix C for
details of wildfire risk zones outside of
(a)Identified areas that are subject to a heightened risk of wildfire,including service area
determinations for such conclusions,and are:
(A)Within the service territory of the Public Utility,and See Section 3.3:Wildfire Risk Zones
(8)Outside the service territory of the Public Utility but within the Public See Section 3.3.2 and Figure 17:Boardman to
Utility's right-of-way for generation and transmission assets. Hemingway(132H)Proposed Route Risk Zones
(b)Identified means of mitigating wildfire risk that reflects a reasonable See Section 4.2:Risk-Based Cost and Benefit of
balancing of mitigation costs with the resulting reduction of wildfire rislmo Wildfire Mitigation A
(c)Identified preventative actions and programs that the Public Utility will See Section 5:Situational Awareness;Section 6:
carry out to minimize the risk of utility facilities causing wildfire. Mitigation—Field Personnel Practices;Section 7:
Mitigation—Operations;Section 8:Asset
Management and Inspection Initiatives;and
Section 8.7:Vegetation Management
(d)Discussion of outreach efforts to regional,state,and local entities, See Section 10.1:Objective and Section 10.2:
including municipalities regarding a protocol for the de-energization of Community Engagement
power lines and adjusting power system operations to mitigate wildfires,
promote the safety of the public and first responders and preserve health and See Appendix B:Idaho Power's Public Safety
communication infrastructure. Power Shutoff Plan,10.1:Community
Engagement and Section 10.4:Customer
Communications
(e)Identified protocol for the de-energization of power lines and adjusting of See Section 7.5:Public Safety Power Shutoff and
power system operations to mitigate wildfires,promote the safety of the Appendix B:Idaho Power's Public Safety Power
public and first responders and preserve health and communication Shutoff Plan
infrastructure,including a PSPS communication strategy consistent with OAR
860-300-0040 through 860-300-0050.
(f)Identification of the community outreach and public awareness efforts See Section 10:Communicating About Wildfire
that the Public Utility will use before,during and after a wildfire season,
consistent with OAR 860-300-0040 and OAR 860-300-0050.

Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
Oregon Requirement—OAR .1 1 1 1 1 1 Corresponding Location in WIVIIP
(g)Description of procedures,standards,and time frames that the Public For Transmission,see Section 8.4:Transmission
Utility will use to inspect utility infrastructure in areas the Public Utility Asset Management and Inspection Initiatives
identified as heightened risk of wildfire,consistent with OAR 860-024-0018. (with information on aerial,ground,detailed
visual,pole,and other protection programs)
For Distribution,see Section 8.5:Distribution
Asset Management and Inspection Initiatives
(with information on visual,pole,and line
equipment inspection programs)
(h)Description of the procedures,standards,and time frames that the Public See Section 8.7.4 Transmission Vegetation
Utility will use to carry out vegetation management in areas the Public Utility Management and Section 8.7.5:Distribution
identified as heightened risk of wildfire,consistent with OAR 860-024-0018. Vegetation Management
(i)Identification of the development implementation,and administrative See Section 4:Mitigation Approach
costs for the plan, which includes discussion of risk-based cost and benefit
analysis,including consideration of technologies that offer co-benefits to the
utility's system.
(j)Description of participation in national and international forums,including See Section 2:Government,Industry,and Peer
workshops identified in section 2,chapter59Z Oregon Laws 2021,as well as Utility Engagement
research and analysis the Public Utility has undertaken to maintain expertise
in leading edge technologies and operational practices,as well as how such
technologies and operational practices have been used to develop and
implement cost effective wildfire mitigation solutions.
(k)Description of ignition inspection program,as described in Division 24 of See Section 8:Asset Management and Inspection
these rules,including how the utility will determine,and instruct its Initiatives and Section 8.6:Ignition Tracking and
inspectors to determine,conditions that could pose an ignition risk on its own Analysis
equipment and on pole attachments.
Risk Analysis—OAR 860-300-0030
Oregon R-. • .1 1 1 1 1 1 Corresponding
(1)The Public Utility must include in its Wildfire Mitigation Plan risk analysis See Section 3:Quantifying Wildland Fire Risk
that describes wildfire risk within the Public Utility's service territory and
outside the service territory of the Public Utility but within the Public Utility's
right of way for generation and transmission assets. The risk analysis must
include,at a minimum: See Section 3.3:Wildfire Risk Zones,Appendix C
WMP map book,and risk zone map on Idaho
(a)Defined categories of overall wildfire risk and an adequate discussion of Power's website for detailed map of wildfire
how the Public Utility categorizes wildfire risk. Categories of risk must risk zones
include,at a minimum:
(A)Baseline wildfire risk, which include elements of wildfire risk that are See Section 3.2 for discussion of fixed
expected to remain fixed for multiple years.Examples include topography, risk elements.
vegetation,utility equipment in place,and climate.
(B)Seasonal wildfire risk, which include elements of wildfire risk that are See Section 3.2.1 for discussion of variable risk
expected to remain fixed for multiple months but may be dynamic elements that change throughout the year.
throughout the year or from year to year;Examples include cumulative
Page 2

2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
Oregon Requirement—OAR 860-300-0030 Corresponding Location in WIMIP
precipitation,seasonal weather conditions,current drought status,and fuel See Section 3.2.1 paragraph 4 addresses the
moisture content. consideration of residential areas in risk analysis.
(C)Risks to residential areas served by the Public Utility;and See Section 3.2.1 paragraph 4 addresses
overhead power lines. Note:Idaho Power does
not model wildfire progression or spread within
substations due to zero vegetation within the
(D)Risks to substation or powerline owned by the Public Utility. fenced area
Also see Section 3.3.2 for discussion of risk
modeling of proposed Boardman to Hemingway
transmission line
(b)a narrative description of how the Public Utility determines areas of See Section 3.2.1:Wildfire Risk Modeling
heightened risk of wildfire using the most updated data it has available from Process and Section 11.4 Wildfire Risk Map
reputable sources.
(c)a narrative description of all data sources the Public Utility uses to model See Section 3.2.1:Wildfire Risk Modeling Process
topographical and meteorological components of its wildfire risk as well as and the 2023 Risk Modeling Input Updates,and
any wildfire risk related to the Public Utility's equipment. Section 11.4 Wildfire Risk Map
(A)The Public Utility must make clear the frequency with which each source See Section 3.2.1:Wildfire Risk Modeling
of data is updated;and Process.,and Section 11.4 Wildfire Risk Map for a
discussion of data source updates
(e)The Public Utility must make clear how it plans to keep its data sources as
up to date as is practicable.
(d)The Public Utility's risk analysis must include a narrative description of
how the Public Utility's wildfire risk models are used to make decisions
concerning the following items:
(A)Public Safety Power Shutoffs A) See Section 7.5 PSPS
(8)Vegetation Management, B) See Section 8.7:T&D Vegetation
Management
(C)System Hardening,
C) See Executive Summary on Infrastructure
(D)Investment decisions;and Hardening;Section 8.5: Distribution Asset
Management and Inspection Initiatives;
(E)Operational decisions. Section 11.9: Long-Term Metrics
D) Risk analysis informs Tier 2 and Tier 3
mitigation activities.See Section 4:
Mitigation Approach and Section 4.5 Wildfire
Mitigation Activities
E) See Section 7 Mitigation-Operations and
Appendix A:Wildland Fire Preparedness and
Prevention Plan
(e)For updated Wildfire Mitigation Plans,the Public Utility must include a See Section 3.2.2 Establishing Wildfire Risk Zones
narrative description of any changes to its baseline wildfire risk that were and Section 3.3 Wildfire Risk Zones
made relative to the previous plan submitted by the utility,including the

Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
Oregon Requirement—OAR .1 1 1 1 1 1
Public Utility's response to changes in baseline wildfire risk,seasonal wildfire
risk,and Near-term Wildfire Risk.
(2)To the extent practicable,the Public Utility must confer with other state See Section 3.2.2.,specifically incorporating local
agencies when evaluating the risk analysis included in the Public Utility's feedback into risk zone establishment and
Wildfire Mitigation Plan. wildfire risk zone calibration with peer utilities
Wildfire Mitigation Plan Engagement Strategies—OAR 860-300-0040
Oregon Requirement—OAR .1 11 1141 Corresponding
(1)The Public Utility must include in its Wildfire Mitigation Plan a Wildfire See Section 10:Communicating About Wildfire
Mitigation Plan Engagement Strategy. The Wildfire Mitigation Plan
Engagement Strategy will describe the utility's efforts to engage and
collaborate with Public Safety partners and Local Communities impacted by
the Wildfire Mitigation Plan in the preparation of the Wildfire Mitigation
Plan and identification of related investments and activities. The Engagement
Strategy must include,at a minimum: See Section 10.2:Community Engagement
(a)Accessible forums for engagement and collaboration with Public Safety
Partners,Local Communities,and customers in advance of filing the Wildfire
Mitigation Plan. The Public Utility should provide,at minimum:
See Section 10.2:Community Engagement,
(A)One public information and input session hosted in each county or Section 10.4.1:Key Communication Methods,
group of adjacent counties within reasonable geographic proximity and and Section 10.4.3 Communication Metrics
streamed virtually with access and functional needs considerations;and
(8)One opportunity for engagement strategy participants to submit
follow-up comments to the public information and input session.
(b)A description of how the Public Utility designed the Wildfire Mitigation See Section 10.2:Community Engagement and
Plan Engagement Strategy to be inclusive and accessible,including Section 10.4.1:Key Communication Methods
consideration of multiple languages and outreach to access and functional
needs populations as identified with local Public Safety Partners.
(2)The Public Utility must include a plan for conducting community outreach See Section 10.2:Community Engagement and
and public awareness efforts in its Wildfire Mitigation Plan.It must be Section 10.4.1:Key Communication Methods
developed in coordination with Public Safety Partners and informed by local
needs and best practices to educate and inform communities inclusively
about wildfire risk and preparation activities.
(a)The community outreach and public awareness efforts will include plans For(A)—(D),see Section 10.2:Community
to disseminate informational materials and/or conduct trainings that cover: Engagement;Section 10.4:Customer
Communications;and Section 10.4.1: Key
(A)Description of PSPS including why one would need to be executed, Communication Methods
considerations determining why one is required,and what to expect
before,during,and after a PSPS,
(8)A description of the Public Utility's wildfire mitigation strategy,•
(C)Information on emergency kits/plans/checklists;
(D)Public Utility contact and website information.
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2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
Oregon Requirement—OAR .1 1 1 1 1 1 Corresponding Location in WMP
(d)Discussion of outreach efforts to regional,state,and local entities,
including municipalities regarding a protocol for the de-energization of
power lines and adjusting power system operations to mitigate wildfires,
promote the safety of the public and first responders and preserve health and
communication infrastructure.
(b)In formulating community outreach and public awareness efforts,the
Wildfire Mitigation Plan will also include descriptions of:
For(A)-(C):See Section 10.2:Community
(A)Media platforms and other communication tools that will be used to Engagement;Section 10.4:Customer
disseminate information to the public, Communications,and Section 10.4.1:Key
Communication Methods
(e)Frequency of outreach to inform the public;
(C)Equity considerations in publication and accessibility,including,but
not limited to:
(i)Multiple languages prevalent to the area;
(ii)Multiple media platforms to ensure access to all members of a Wl
Local Community.
(3)The Public Utility must include in its Wildfire Mitigation Plan a description See Section 10.4.3:Communication Metrics
of metrics used to track and report on whether its community outreach and
public awareness efforts are effectively and equitably reaching Local
Communities across the Public Utility's service area.
(4)The Public Utility must include a Public Safety Partner Coordination See Section 10.2.:Community Engagement
Strategy in its Wildfire Mitigation Plan. The Coordination Strategy will
describe how the Public Utility will coordinate with Public Safety Partners
before,during,and after the fire season and should be additive to minimum
requirements specified in relevant Public Safety Power Shut Off requirements
described in OAR 860-300-0050. The Coordination Strategy should include,at
a minimum:
(a)Meeting frequency and location determined in collaboration with
Public Safety Partners;
(b)Tabletop Exercise plan that includes topics and opportunities to
participate;
(c)After action reporting plan for lessons learned in alignment with Public
Safety Partner after action reporting timeline and processes.

Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
Response to OPUC Staff Recommendations
OPUC Order No. 24-231 and 24-326
The following sections address recommendations received from the OPUC Staff in Docket
No. UM 2209 and UM2340 and approved by the OPUC in Order No. 24-231 and Order 24-326,
respectively. The italicized text reflects the OPUC staff specific recommendations.
Staff recommendations from Order No. 24-231 indicated for the 2026 WMP filing are not
included below. On December 31, 2024, Idaho Power filed a comprehensive 2025 Wildfire
Mitigation Plan which includes all key plan elements for the 2025 calendar year.
Idaho Power Recommendations (Order 24-231)
OAR 860-300-0020(1)(a)(A) and (B)
(1) Explain the rationale for the 240-meter buffer around assets.
Response: Idaho Power's models ignitions 120M on either side of an overhead
powerlines, resulting in a 240-meter buffer around assets. This distance extends
modeled ignitions outside of roadways (necessary as models generally classify road
mediums as unburnable) without overestimating modeled ignition relative to powerline
infrastructure. The buffer distance additionally enables gradients in modeling, which is
necessary for identifying and comparing outputs.
(2) Provide explanation of the method Idaho Power used to differentiate Yellow Risk Zones
(YRZs)from Red Risk Zones (RRZs) (particularly with the recent modification of the area
around Halfway, which transitioned to a Red Risk Zone).
Response: Idaho Power uses the terms Tier 3 and Tier 2 to identify its wildfire risk zones.
Tier 3 is color coded red on maps and Tier 2 is color coded yellow. Idaho Power infers
that this recommendation applies to Tiers 3 and 2. Section 3.2.1 details Idaho Power's
process for risk modeling. Section 3.2.2 of the WMP details Idaho Power's process for
establishing wildfire risk zones. These processes were utilized during Idaho Power's
wildfire risk model update completed in 2023, resulting in changes to risk zones in
Oregon.
OAR 860-300-0020(1)(b)
(4) Explain how risk mitigation results in changes in utility risk.
Response: Section 4.2 of Idaho Power's 2025 WMP discusses the company's framework
for understanding the potential consequences of wildfire damage and the possibility of
diminishing those consequences through targeted mitigation activities. In 2024, Idaho
Power began work to enhance existing risk quantification methods by integrating asset
parameters, such as age, conductor type, phasing, and outage history, into the company's
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2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
existing risk data.The team will continue this work in parallel with the implementation of
new wildfire risk modeling software, Technosylva, to ultimately lead to a detailed
distribution circuit-specific analysis.This analysis will also help establish a baseline that
will enable calculation of the risk reduction benefit (RSE)from specific
mitigation practices.
OAR 860-300-0020(1)(c)
(5) Continue evolution of Tables 7 and 9, detailing state-level annual estimates and units for
each mitigation tactic, with the resulting estimated risk reduction.
Response: A state-level break down is included in Tables 7 and 9 in the 2025 WMP.
Section 4.5.1., Quantifying Wildland Fire Risk, details Idaho Power's ongoing efforts to
estimate risk reduction associated with each mitigation tactic.
OAR 860-300-0020(1)(d)
(6) Include details about command structure used during emergency activation, whether
National Incident Management System (NIMS), Incident Command System (ICS), or other
standards.
Response: Idaho Power's process and command structure for PSPS activations is
detailed in Appendix B, Idaho Power Company's Wildfire Public Safety Power Shutoff
Plan. In 2024, members of the Idaho Power Wildfire Mitigation team who are
responsible for PSPS protocol participated in FEMA Incident Command System Training
resulting in certificates of completion for FEMA ICS-100 and ICS-200 courses.
(7) Identify general frequency and types of interactions with public safety partners.
Response: Section 9.5, Public Outreach and Communications, and Section 10.2,
Community Engagement, of the 2025 WMP provide a detailed description of the process
and frequency of annual interactions with public safety partners. Appendix B, Idaho
Power Company's Wildfire Public Safety Power Shutoff Plan, details frequency and
interactions with public safety partners during active PSPS events.
OAR 860-300-0020(1)(e)
(9) Identify Community Based Organizations who are participating in community outreach
supportive of Public Safety Power Shutoffs and what specific actions they are taking.
Response: Unlike more populus portions of Oregon, the portion of eastern Oregon that
the company serves has very few community-based organizations, let alone
organizations with the capacity to participate in community outreach for PSPS.
The company approaches its outreach and engagements efforts for the WMP and PSPS
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Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
plan by identifying and targeting effort to reach as many stakeholders as possible,
including public safety partners, critical facilities, and the community.
Each year, prior to wildfire season, communications begin with public safety partners,
including the Idaho and Oregon state offices of emergency management, county
emergency managers, local governments, and social service and welfare agencies.
These communications are held both individually and in larger groups during Local
Emergency Planning Committee meetings, where the company provides an overview of
the WMP and discusses the PSPS plan and outage preparation. A detailed list of Idaho
Power's 2024 meeting efforts is included in table 17 of the 2025 WMP.
Additionally, to ensure messaging reaches access and functional needs customers,
the company collaborates with the Living Independent Network Corporation,
the Southwest Idaho Area Agency on Aging, and Norco to present outage preparedness.
The information provided includes considerations for older adults and individuals with
disabilities, and information about medical equipment considerations during an outage.
(10) Discuss how Empower is used in Idaho Power's Oregon service territory.
Response:The Health and Human Services emPOWER Program offers a secure tool
which allows local public health personnel access to addresses for individuals utilizing
Medicare who have been provided durable medical devices. Idaho Power has tested our
mapping capabilities with HHS to ensure we are able to provide outage boundary files
compatible with emPOWER. When conducting pre-season outreach with county
partners, Idaho Power includes an overview of the EmPOWER program, and how to
utilize the system during PSPS events. To-date, the Oregon counties we serve have not
elected to participate with the program.
(11)As appropriate, identify how customers are able to use battery rebate or other programs to
improve resilience to events such as Public Safety Power Shutoffs.
Response: Idaho Power does not currently offer a battery rebate program. Section 10.2
provides a comprehensive overview of the company's approach to outreach and
engagement around the WMP and PSPS, including communications during a PSPS,
wildfire prevention, community resilience efforts, and emergency outage preparedness.
OAR 860-300-0020(1)(g)
(14)Discuss timing of inspection and correction frequency inside and outside high fire risk areas.
Response:Table 13 in the 2025 WMP provides a summary of asset inspections and schedule
by state and risk zone. Corrective action plans for defects are determined by engineering
personnel consistent with standards governing the correction of defects and subsequently
scheduled and repaired consistent with OAR 860-024-0018.
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2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
(15)Discuss and demonstrate the use of ignition risk driver analysis and ignition historic analysis to
determine optimal timing and completion of inspection and correction activities.
Response: Section 8.6 of the 2025 WMP discusses Idaho Power's Ignition Tracking and
Analysis.This ongoing work will continue to support the determination of optimal timing
and completion of inspection and correction work.
OAR 860-300-0020(1)(h)
(16) Discuss evolution of vegetation management program based on long term metrics
developed in the Plan; where possible, continue to explore the relationship between fire history,
outage history, and other indicators of optimization of the vegetation management program
elements and provide information about learnings within the WMP.
Response: Section 4.5.6. and Section 8.7 of the 2025 WMP discuss Idaho Power's enhanced
vegetation management practices, including considerations over time that have led to the
company's current approach for vegetation management. Idaho Power continues to track
metrics to assess efficacy of the vegetation management program and through this has
identified notable long-term co-benefits, including reduced vegetation-caused outages
in Tier 3 and Tier 2 risk zones. For example, the 2023 wildfire season saw an increased
number of storm events, high winds, and more lightning throughout the service area
than in previous years. While storm activity was higher, outages associated with
vegetation fell by 27% compared to previous years—indicating that the company's
vegetation management practices are reducing risk. Section 11.9 of the 2025 WMP
provides additional discussion of how long-term metrics are used to assess
WMP effectiveness.
In 2024, the company began work combining analytics with vegetation management
activities by developing a probabilistic model called Vegetation Risk Index (VRI). The VRI
is intended to help Idaho Power quantify the likelihood of vegetation contact under
specific conditions, such as extreme weather events. The model considers variables such
as tree density, species, outage history, and meteorology data, which helps provide
insight into how atmospheric conditions may impact growth rates of certain species and
where certain high-risk vegetation areas may exist as conditions change. The model is
anticipated to provide a co-benefit of informing where Idaho Power may want to focus
additional tree inspection activities in advance of wildfire season or on certain high-risk
days that include PSPS events. Work performed thus far has demonstrated the potential
benefits of combining innovative analytics with traditional mitigation practices to
enhance reliability, reduce risks, and ensure public safety. Idaho Power anticipates
completing an initial version of the VRI in 2025 and will begin utilizing it once it is
finalized.
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Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
OAR 860-300-0020(1)0)
(18) Report on results of joint utility maturity model pilot work and continue advancing wildfire
maturity rubric in alignment with International Wildfire Risk Mitigation Consortium (IWRMC).
Response: In 2024, Idaho Power completed the IWRMC maturity model, and analyzed
and benchmarked data to inform maturation focus. Idaho Power identified four
categories for maturation over the next three years. Categories, capabilities, approach
for maturation, and associated implementation timelines are discussed in Section 1.5 of
the 2025 WMP.
OAR 860-300-0020 (1)(k)
(19)Provide history and other indicators of optimization of the vegetation management
program elements and provide information about learnings within the WMP.
Response: Section 4.5.6. and Section 8.7 of the 2025 WMP discuss Idaho Power's
enhanced vegetation management practices, including the company's consideration of
other vegetation management alternatives, including shorter trimming cycles, longer
trimming cycles, and strategies that evaluate each tree individually and only trim it once
it has nearly grown back to the power line (known as "just-in-time trimming").
Each alternative presented challenges or resulted in negative impacts that undermined
potential benefits. The company continues to pursue additional data acquisition and
analytics on its vegetation management program to assess trimming cycle optimization.
Joint Utility Recommendations Order 24-326
(24-230-A)All utilities should provide Plans that allow a determination on compliance within the
body of its Wildfire Mitigation Plan.
Response:Appendix D of Idaho Power's 2025 Wildfire Mitigation Plan meets this
recommendation.The standard WMP format discussed in 24-230-D will meet the requirements
of 24-230-A for the company's 2026 filing.
(24-230-B)All utilities should provide multi-year Plans which are updated on an annual basis.
Response: Idaho Power filed its 2025 Wildfire Mitigation Plan consistent with the requirements
of 24-326. Idaho Power will file a multi-year plan beginning with the 2026 WMP.
(24-230-C)All utilities should participate in a joint utility effort to move towards use of shared
terminology throughout the WMPs. The utilities must agree upon and use a standard WMP glossary
which articulates shared terminology, and any differences in use of terminology between the utilities
in the 2026 Plans.
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2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
Response:As described as part of the Phase 2 work in Order 24-230, Idaho Power is
collaborating with Pacific Power and Portland General Electric on a glossary of shared
terminology that will be included in the 2026 WMP filing.
(24-230-D)All utilities should provide WMPs in a standard format which adopts uniform chapter
and section headings, as well as other agreed upon organizational features.
Response:As described as part of the Phase 2 work in Order 24-230, Idaho Power is
collaborating with Pacific Power and Portland General Electric on a standard WMP format with
uniform chapter and section headings and other agreed upon organizational features.
(24-230)All utilities should provide the program level details though standard reporting templates.
Response: Standard reporting templates were approved in Order 24-326 at the September 19,
2024, Public Meeting.The data tables for reporting preliminary results for the first through third
quarters of 2024 are included with this filing and final,full year 2024 data will be filed by
March 31, 2025.
(24-230-F)All utilities should provide inspection and correction data through a standard reporting
template which facilitates comparisons of inspection functions, costs(at unit level), and amount of
work across the IOUs(and potentially bench markable across a broader region).
Response: Standard reporting inspection and correction reporting templates were approved in
Order 24-236 326 at the September 19, 2024, Public Meeting. Data Tables 3-T&D Inspection and
4-T&D Correction with reporting preliminary results for the first through third quarters of 2024
are included with this filing and final,full year 2024 data will be filed by March 31, 2025.
(24-230-G)All utilities should provide vegetation management data through a standard reporting
template which facilitates comparison of inspection functions, costs, and amount of work across the
IOUs. Given the large costs expended or forecasted to achieve 'optimal"clearance, a standard data
template should include information about vegetation management program administration, work
scopes, and costs by clearance objectives.
Response: Standard reporting inspection and correction reporting templates were approved in
Order 24-326 at the September 19, 2024, Public Meeting. Data Table 5-Vegetation Management
with reporting preliminary results for the first through third quarters of 2024 is included with this
filing and final,full year 2024 data will be filed by March 31, 2025.
(24-230-H)All utilities should provide industry engagement information though a standard
reporting template which outlines participation in industry forums and expected information to be
shared in such forums, including results from pilots prior to widescale adoption, and pilot
valuation methods.
Response:As part of the Phase 2 work described in Order 24-230, Idaho Power is collaborating
with Pacific Power and Portland General Electric on a standard template for reporting
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Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
participation in industry forums as part of the standard WMP template described in
Recommendation 24-230-D.
(24-230-1)All utilities should provide pilot technology information though a standard reporting
template which includes details of pilot projects, goals for the pilot, status of the pilot(planning,
development, implementation), the current penetration and saturation across the system,
envisioned application, milestones for determining usefulness of pilot, expected capital costs,
expected O&M costs, expected timeframe for pilot implementation and lifespan.At minimum,
this level of detail is needed for the following pilot technologies:
• Communicating Fault Circuit Indicators(CFCI).
• Fuel load reduction projects.
• Wildfire detection cameras.
• Early fault detection.
• Drone inspection pilot.
• Distribution fault anticipation
• Covered conductor or spacer cable;and
• Infrared patrols.
Response:As part of the Phase 2 work described in Order 24-230, Idaho Power is collaborating
with Pacific Power and Portland General Electric on a standard template for reporting
pilot technologies.
(24-230-J)All utility risk maps should originate from a foundational utility risk map which considers
the logical set of variables. Short range outlooks, as well as mid-range outlooks may inform the
foundational map.After developing the foundational map, a utility risk map can consider and
overlay a variety of conditions, such as response times and locale as well as locations where
mitigations have taken place or recent fuel has been removed.Any adjustments made to the
foundational risk maps or the outlooks, should be explicitly identified and recorded as to what
variable caused the change and what new information supported this change.
Response: Idaho Power's process for establishing wildfire risk zones is discussed in detail in
section 3 of the 2025 WMP
(24-230-K)All utilities should collaborate to calibrate their risk modeling methods and identify the
underlying assumptions in determining line segment risk. Some of the assumptions might include
fire spread modeling periods, probability being considered,fire weather history, and inclusion of
response likelihood.This work approach would result in fundamental agreement on a specific
modeling method for which each utility would produce its current asset register, as well as GIS and
tabular data identifying the risk scoring for each asset.
Response: Idaho Power will participate in the OPUC Staff lead WMP working group described in
Order 24-230 to discuss risk modeling methods and underlying assumptions in determining line
segment risk.
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2025 Oregon Wildfire Requirements and Recommendations Idaho Power Company
(24-230-L)The WMP working group should adopt Risk Mitigation and Cost Valuation (RSE) as part
of its area of focus.This Staff led working group should propose risk quantification guidelines to the
Commission for implementation in the 2026 WMPs. RSE should reflect granular data for electric
assets which quantify risk that is derivative of operational data (include outage and device state
information), observational data (inspections),temporal data (snapshots in time related to
peripheral systems). RSE should also reflect data that fully comprises all the facilities that are part of
the utility's HFRZ. Consistency of terminology, data sources and their confidence, and expected
calculation processes should be prepared by the utilities with consistent guidance by the PUC.
In addition, RSE needs to recognize the way"risk" is quantified by the utility, result in an
agreed-upon method for the quantification and the manner that reduced risk will be measured.
Response: Idaho Power will participate in the OPUC Staff lead WMP working group described in
Order 24-230 regarding risk quantification guidelines.
(24-230-M)All utilities should regularly participate in a cross-utility effort, via working group or
other format, to share experience, learnings, and industry best practices, surrounding system
reliability.At minimum, this effort should include discussion of sophisticated protection control
equipment and its application to sensitive settings, consideration of impact to reliability,
in particular the response during elevated risk season with repeated outages to customers when
"self-healing"is not in place(resulting in them experiencing nuisance trips). This group should not
only consider impacts to system level reliability but consider impacts of momentary interruptions
and longer sustained outages to remote customers, particularly those which may be less able to
sustain during poorer reliability periods.
Response: Idaho Power participates in numerous industry working groups to share best practices
regarding system reliability. See section 2.3. Industry and Peer Utility Engagement of Idaho
Power's 2025 WMP.
(24-230-N)All utilities should regularly participate in a cross-utility effort, via working group or other
format, to share experience, learnings, and industry best practices,for identifying and coordinating
with Public Safety Partners, building on the ground relationships and communication, developing
livestream/recorded multi-language community meetings, and coordinate with local communities
to participate in safety fairs.
Response: Idaho Power participates in numerous industry working groups to share best practices
regarding coordinating with Public Safety Partners. See section 2.3. Industry and Peer Utility
Engagement of Idaho Power's 2025 WMP
(24-230-0)All utilities should collaborate to develop consistent content(and should conform to
generally consistent language)to inform customers, communities and public safety partners about
operational protocols which can impact their power reliability and power system operations.As a
complement to these approaches, utilities should perform analysis regarding the location-specific
impacts to reliability, including the increase in customer complaints internally as well as those
recorded by the OPUC consumer services division, and develop methods to quickly react to
heightened operations impacting customers'reliability. Customers and communities may benefit
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Idaho Power Company 2025 Oregon Wildfire Requirements and Recommendations
from awareness of other outage causes(beyond weather), which impact reliability and during
"sensitive settings"or 'fire season"period or which could result in unusual reliability.
Response: Idaho Power attended a one-day workshop hosted by Pacific Power on November 19,
2024, in Portland, Oregon to meet with communications teams from western utilities to discuss
wildfire communications. Events included discussions on internal communications, digital media,
paid media, media relations, community engagement, lessons learned from the 2024 wildfire
season with a look ahead to 2025 challenges. Communications teams were invited from Alta Link,
ATCO,Avista, Fortis Alberta, Fortis BC, NV Energy, Pacific Gas and Electric, Pacific Power,
Portland General Electric, Puget Sound Energy, Rocky Mountain Power, San Diego Gas and
Electric, and Xcel.Two additional workshops are planned for March and November 2025.
Idaho Power is reporting customer reliability complaints and inquiries and OPUC recorded
reliability complaints in Table 7-Risk Performance of the data templates submitted as part of
this filing.
(24-230-P)All utilities should collaborate to develop a "template" for reporting PSPS details during
the execution of a PSPS.
Idaho Power will collaborate with Pacific Power and Portland General Electric to develop a
template for reporting the details of a PSPS event.This work will be initiated following the
completion of Phase 2 work as described in Order 24-230.
Page 14