20260120APPLICATION.pdf

C01-E-26-01
RECEIVED
From: Robert Pierce January 20, 2026
To: secretary IDAHO PUBLIC
Cc: Donn English;Jason Talford; Kimberly Loskot;Telly Stanger UTILITIES COMMISSION
Subject: 2026 WMP Filing
Date: Monday,January 19,2026 1:37:39 PM
Attachments: imaoe001.Dna
CPC WMP 2026 .Ddf
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Commission Secretary,
Attached please find the 2026 Wildfire Mitigation Plan for Clearwater Power Company.
Please consider this as our official filing with the Idaho Public Utilities Commission. If
you have any questions, please contact me directly.
Sincerely,
Bob Pierce,
Chief Operating Officer
C L E A RWAT E R
P O W E R C O M P A N Y
208.798.5203 Direct 1208.743.1501 Ext: 2031208.791.1372
4230 Hatwai Road, Lewiston, ID 83501
rdoierce(a)clearwaterpower.com
www.clearwaterpower.com
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CL=ARWAT=R
2026 WILDFIRE
MITIGATION PLAN
APPROVED BY CPC BOARD OF DIRECTORS
December 17, 2025

Contents
1 Introduction ........................................................................................................................ 1
1.1 Purpose of the Plan...................................................................................................... 1
1.2 Objectives of the Wildfire Mitigation Plan (WMP).......................................................... 2
1.3 CPC Profile and History ................................................................................................ 2
1.4 The Service Area.......................................................................................................... 2
1.5 The Electric System...................................................................................................... 3
2 Overview of Fire Prevention Strategies................................................................................ 5
2.1 Timeframes of Preventative Strategies and Programs.................................................. 5
3 Cost-Benefit Approach......................................................................................................... 8
3.1 Mitigation Selection...................................................................................................... 8
4 CPC's Service Territory and Asset Overview ........................................................................ 9
4.1.1 Wildfire Risk in the Service Area ..........................................................................10
4.1.2 Wildland Urban Interface (WUI) ...........................................................................12
4.1.3 Fire Threat Assessment Mapping ........................................................................14
5 Wildfire Prevention Strategy and Programs........................................................................21
5.1 T&D Operational Practices...........................................................................................23
5.1.1 Situational Awareness and Assessment ..............................................................23
5.1.2 Industrial Fire Precaution Levels..........................................................................23
5.1.3 Fire Precautionary Period ....................................................................................24
5.1.4 Recloser Operational Practices............................................................................24
5.1.5 Public Safety Power Shutoff.................................................................................24
5.1.6 Strategy for Re-energization ................................................................................25
5.2 Infrastructure Inspections and Maintenance ...............................................................25
5.2.1 Definition of Inspection Types..............................................................................26
5.2.2 Instructions to Inspectors.....................................................................................27

5.2.3 Line Patrol ...........................................................................................................27
5.2.4 Detailed Transmission & Distribution Inspections.................................................27
5.2.5 Wood Pole Test and Treatment ...........................................................................28
5.2.6 Substation Inspections.........................................................................................28
5.2.7 Standards for Record-Keeping and Reporting......................................................29
5.2.8 GIS Mapping........................................................................................................29
5.3 Vegetation Management .............................................................................................29
5.4 T&D System Vegetation Management Overview.........................................................30
5.4.1 Vegetation Management Trimming Standards .....................................................30
5.4.2 Vegetation to Conductor Clearance Guidelines....................................................30
5.4.3 Vegetation Control Methods.................................................................................32
5.4.4 At-Risk Vegetation...............................................................................................33
5.4.5 Member Requests................................................................................................33
5.4.6 Member-Owned Lines..........................................................................................33
5.4.7 Storm Damage.....................................................................................................33
5.4.8 Clear Cut Right-of-Way Specifications.................................................................33
5.4.9 Tools and Equipment...........................................................................................33
5.5 Fire Mitigation Construction.........................................................................................34
5.5.1 Wood Pole Fire Protection ...................................................................................34
5.5.2 Avian Protection Construction Standards.............................................................35
5.5.3 Underground Conductor.......................................................................................37
5.6 Pilot Projects...............................................................................................................38
5.6.1 Electronic Reclosers with Remote Adjustability....................................................38
5.6.2 Non-expulsion Fuses...........................................................................................38
5.6.3 Drone Inspection Program ...................................................................................38
5.6.4 Satellite Imaging Program....................................................................................38
5.6.5 Weather Stations .................................................................................................38

5.7 Workforce Training......................................................................................................39
6 Emergency Response.........................................................................................................40
6.1 Preparedness and Response Planning .........................................................................40
6.1.1 Emergency Restoration Plan ...............................................................................40
6.1.2 Government Agency Land Partners.....................................................................42
6.1.3 Emergency Management Communication and Coordination................................44
6.1.4 Fire Response and Suppression Capabilities.......................................................44
6.2 Community Outreach ..................................................................................................46
6.2.1 Public Agency and Member Communications for Outages...................................46
6.3 Restoration of Service .................................................................................................46
6.3.1 Service Restoration Process................................................................................46
7 Performance Metrics and Monitoring ..................................................................................47
7.1 Plan Accountability......................................................................................................47
7.2 Monitoring and Auditing of the WMP...........................................................................47
7.2.1 Revising the WMP ...............................................................................................48
7.3 Performance Metrics....................................................................................................48
7.4 Programmatic Quality Assurance/Quality Control processes........................................50
7.4.1 T&D System Inspection QC Process....................................................................50
7.4.2 Vegetation Management QC Process..................................................................51
AppendixA: Disclaimers............................................................................................................52
AppendixB: Glossary ................................................................................................................53
AppendixC: Acronym Guide......................................................................................................58

Tables
Table 1. Mitigation Programs/Activities ..............................................................................................5
Table 2. Mitigation Programs/Activities Continued..............................................................................6
Table 3. Mitigation Programs/Activities Continued..............................................................................7
Table4. Asset Description ...................................................................................................................9
Table 5. Overview of CPC's T&D Assets within WHP Tiers....................................................................15
Table 6. Activities That Address Wildfire Risk Factors ..........................................................................22
Table7. Inspection Cycles................................................................................................................26
Table 8. Performance Metrics...........................................................................................................49
Figures
Figure 1. CPC Service Area and Substations..........................................................................................4
Figure 2. Fire History 2000-2020........................................................................................................11
Figure 3. Wildland Urban Interface within CPC Service Area.................................................................13
Figure 4. CPC Service Area and Wildfire Hazard Potential Overview......................................................16
Figure 5. Wildfire Hazard Potential Map #1.........................................................................................17
Figure 6. Wildfire Hazard Potential Map #2.........................................................................................18
Figure 7. Wildfire Hazard Potential Map #3.........................................................................................19
Figure 8. Wildfire Hazard Potential Map #4.........................................................................................20
Figure 9. Vegetation to Conductor Clearance......................................................................................32
Figure10. Treated Pole....................................................................................................................35
Figure 11. Avian Protection Construction ............................................................................................37
Figure 12. General Land Management................................................................................................43
Figure 13. Fire Protection District Map................................................................................................45

1 Introduction
As we have seen over the past few years, the western United States has experienced some of
the most devastating and catastrophic wildfires in our nation's history. Unfortunately, wildfires
have also become a regular occurrence in Clearwater Power Company's (CPC) service area.
Various Wildfire Mitigation Plan (WMP) regulations have been passed in all the states that CPC
serves. In general, these regulations direct utilities to develop operational policies and practices
to prevent, prepare for and respond to wildfire events.
Fire mitigation plays an essential role in CPC's operational practices. Over the years, CPC has
adopted programs, procedures, and improved operational practices to help mitigate the
potential for utility-caused ignitions and more effectively respond to high wildfire risk conditions.
The strategies, programs and activities included in this WMP, with associated goals and metrics,
are an approach to reduce fire-related risk in the short-term and will allow for refinement and
improvement over time. As CPC gains experience implementing the WMP's mitigation programs
and as new information or technologies emerge, CPC will assess, evaluate, enhance, and refine
its practices. The WMP also addresses vegetation management (VM), asset inspection, system
maintenance, recloser setting protocols, communication plans, and service restoration
processes. Additionally, it identifies responsibilities, performance metrics, mitigation
deficiencies, and an audit and approval process for the plan.
1 .1 Purpose of the Plan
As of April 2025, Idaho has a Wildfire Standard of Care Act (WSCA) which states that
cooperative utilities like CPC may adopt and file a WMP with the Idaho Public Utilities
Commission. Both Oregon and Washington have also passed legislation requiring WMPs for both
investor-owned and consumer-owned utilities. Notwithstanding, CPC believes the development
of a WMP is a prudent and responsible effort to prepare for increased wildfire occurrences in its
service area and plans to submit copies of this WMP to all three states. This plan's primary
objective is to reduce the threat of CPC's infrastructure being an ignition source for wildfires
and to comply with any current or future state(s) WMP regulations.
This plan describes CPC's strategies and programs to help mitigate the threat of electrical
equipment ignited wildfires. It addresses the unique features of CPC's service area such as
topography, weather, infrastructure, grid configuration and potential wildfire risks. While CPC's
Board of Directors approved the plan, its implementation primarily resides with the Chief
Executive Officer (CEO) and the Chief Operating Officer (COO).
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1 .2 Objectives of the Wildfire Mitigation Plan (WMP)
The main objective is to implement an actionable plan for increasing reliability and safety
while minimizing the probability that CPC's electrical network may be the catalyst or
contributing factor in the ignition of a wildfire. All programs and strategies shall comply with
current and proposed laws in all three (3) states where CPC operates and the National
Electric Safety Code (NESC) and Rural Utilities Service's (RUS) regulations and guidelines.
The secondary objective is to measure, through an annual evaluation, the effectiveness of the
specific wildfire mitigation strategies as they are deployed by CPC. Where a particular action,
program component or protocol proves unnecessary or ineffective, CPC will assess whether
modification or replacement is suitable.
1 .3 CPC Profile and History
CPC is one of ten not-for-profit, member-owned cooperative utilities in Idaho. Founded in 1937,
CPC serves approximately 11,900 meters throughout portions of eleven counties in Idaho,
Washington, and Oregon. CPC strives to uphold a commitment to service excellence while
delivering safe, affordable, and reliable electricity to its members.
CPC members elect a seven-member Board of Directors that determines policy and appoints
the CEO who is responsible for CPC's overall management and operations. CPC owns and
operates nearly 3,000 miles of power line and maintains more than 11,000 acres of right-of-way
to provide electric service to its members. CPC's distribution system is well maintained, as CPC
follows RUS design and construction specifications and has a robust pole test, treatment, and
replacement program.
1 .4 The Service Area
CPC serves a large and diverse service area. Stretching 107 miles from Plummer, Idaho in the
north to Flora, Oregon in the south, and more than 63 miles from Weippe, ID to beyond
Cloverland, Washington. The service area spans three (3) states, two (2) tribal nations', and
eleven (11) counties2. While the main office is located in Lewiston, ID, the service area covers
approximately 5,000 square-miles in very rural and remote areas with an average density of 4
members per mile.
The service area is dominated by open spaces, whether used for farming, grassland, or open
range. Some forest land exists and there are dramatic canyons and hillsides, especially along
the Snake and Clearwater Rivers, but also streams and creeks. These slopes can be focal points
for wildfire, especially when strong winds blow through the canyons. CPC's right-of-way is
primarily located on privately-owned property; however, a small portion crosses State and
Federal land. Roughly 30%, or 900 miles, of CPC's overhead lines are in wooded areas.
' Coeur d'Alene and Nez Perce Tribal Lands
z Idaho: Benewah, Clearwater, Idaho, Latah, Lewis, Nez Perce, Shoshone. Washington: Asotin,
Garfield, Whitman. Oregon: Wallowa
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2026 Wildfire Mitigation Plan

Elevations range from approximately 1,000 feet in the Clearwater River valley to approximately
4,700 feet on the peak of Craig Mountain near the southern end of the service area.
Much of the CPC service area is in Agronomic Zone 2 for the Dryland Northwest, with areas
closer to the rivers in Zone 3. Both zones are characterized by slopes of 10 to 40 percent,
with moderate temperatures in both winter and summer. The CPC service area is generally
less hot and dry than the areas of central Washington and Oregon, which are in zones 4-6.
The warmest days generally occur from late June through mid-September3.
1 .5 The Electric System
CPC owns and operates an electric system that includes transmission and distribution assets.
As of 2024s RUS Financial and Operating Report, the system is comprised of 81 miles of
transmission line (34.5kV, 69kV, and 115kV), 2,558 miles of overhead (OH) distribution line
and 385 miles of underground (UG) line (7.2kV — 14.4kV). CPC operates 21 power substations,
some of which are owned or shared with the Bonneville Power Administration (BPA) and Avista
(Figure 1).
The main office and operations center is in Lewiston, Idaho. CPC has two additional
warehouses; one just outside of Ahsahka, Idaho and the other in Princeton, Idaho.
3 https://weatherspark.com/y/145394/Average-Weather-at-Lewiston%E2%80%93Nez-Perce-County-Airport-Idaho-
U n ited-States-Yea r-Round
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Figure 1. CPC Service Area and Substations
Spokane -'
County
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Tensed Benewah
County
Brincken's Fernwood Shoshone
Corner' County
Whitman '- - Sanders __
cs,sr
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Clearwater
Genesee I Juliaetta (AVA) County
Coun
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Hilltop I Ahsahka
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jI- - r -J Orofino (AVA)
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1 Asotin JNez Perce I r
I County County I r J Weippe (AVA)
Idaho
Anatone I r County
r Craigmont (AVA)
_ Spalding Sweetwater(AVA)
Wallowa
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I� E_n.-1EFE n— SafeGraDF FAO METI.NASA.LSGS Bureau of Lard Varagement EPA.NPS,USGS
Clearwater Power Company Service Territory N
Service Boundary A Substation 34.5 kV Sub-transmission 14.4 kV Distribution
County Boundary 115 kV Transmission 69 kV Sub-transmission 7.2 kV Distribution
0 CPC Owned Substation = Substation owned by other utility *BPA-owned stepdo%vn transformer
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2026 Wildfire Mitigation Plan

2 Overview of Fire Prevention Strategies
CPC's proposed wildfire prevention strategies are comprised of five main components (Tables 1-
3). Together they create a comprehensive wildfire preparedness and response plan with a
principal focus on construction standards, ignition prevention through system design,
operations, inspection and maintenance programs, and emergency planning.
Table 1 - 3 summarizes CPC's programs and activities that support wildfire prevention and
mitigation along with a timeframe for implementation.
2.1 Timeframes of Preventative Strategies and Programs
The five components have several strategies and programs including some that are situational
and not limited to any timetable, scheduled for completion over several years, under evaluation,
or in the initial stages. Targets, scheduled timeframes, and programmatic metrics are in Chapter
4. The strategies and programs below fall into one or more of the five implementation
timeframes:
• A: Currently implemented
• B: Implemented before the upcoming Fire Precautionary Period
• C: Completed annually or on schedule per relevant code
• D: In evaluation or development
• E: Implemented on as-needed basis and protocols in place
• * Ongoing program with no defined completion date
Table 1. Mitigation Programs/Activities
DESIGN AND CONSTRUCTION
Strategic undergrounding of distribution lines Al
Install animal guards as required on jumpers and transformers A*
Reduced span length in high wind areas A* I
Avian protection program A*
Increased phase spacing A*
Fire-resistant coating or wrap on high-risk wood poles A*
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Table 2. Mitigation Programs/Activities Continued
INSPECTION AND MAINTENANCE
Infrared inspections of substation equipment A
Drone inspection program
Satellite Imagery of ROW with AI prioritization A
Transmission line ground patrols
T&D wood pole testing and treatment C
T&D vegetation right-of-way maintenance M
Distribution system line patrols and detailed inspections C
Enhanced line patrols in high-risk areas prior to Fire Precautionary B
Period
T&D system vegetation management program A
Increased community outreach/wildfire safety awareness B
Alternate recloser practices during fire weather conditions A
SITUATIONAL
Weather Monitoring (USFS-WFAS, NWS) A*
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Table 3. Mitigation Programs/Activities Continued
RESPONSE AND RECOVERY
Public Safety Power Shutoff (PSPS) Protocols D
Coordination with local Department of Emergency Management A*
Line patrols before re-energization A*
Emergency Response Plan A
Mutual Aid Agreements A
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3 Cost-Benefit Approach
In Idaho, the WSCA requires that CPC perform a reasonable balancing of the costs of mitigation
with reduction of wildfire risk. This section details CPC's risk based cost and benefit approach to
selecting wildfire mitigations.
CPC found that obtaining a precise calculation of the potential costs of future wildfires is not
possible. We can all agree that the costs of wildfires can be immense and can include human
lives, property, fire suppression costs and litigation. For example, the nearby Gray fire in
Spokane County, Washington burned over 10,000 acres, destroyed 259 structures and the
death of one person was determined to be connected to the fire. This damage will likely result
in hundreds of millions of dollars in claims against the electric utility serving in that area. In the
state of California, the costs and damages of the 2025 Los Angeles wildfires are estimated be
between $28 billion and $53 billion.
In July of 2024, the lightning ignited Gwen fire burned over 60 structures and caused over $2
million in infrastructure damage to CPC's system. In complete contrast, CPC has also had years
like 2025 where we did not experience any fire damage at all. This disparity is why calculating
wildfire cost is impossible.
3.1 Mitigation Selection
CPC's mitigation selection is mainly driven by the identification of Wildfire Hazard Potential
(WHP) zones which are described in section 4. This approach allows CPC to direct its mitigations
toward the geographic areas and infrastructure that may be subject to heightened wildfire risk
and to employ mitigations that are most likely to achieve a reduction in wildfire risk.
Risk-informed Planning and prioritization. Mitigation is generally prioritized to circuits and
segments with the highest WHP where potential benefits are expected to be the greatest.
Strategic reliance on pilot projects.
Pilot programs are used to calibrate benefit relative to cost, labor and time. This allows CPC to
assess the learnings associated with each pilot project and when CPC deems appropriate, make
a case-by-case determination as to whether to scale up that program.
Performance monitoring and adaptive management. CPC tracks implementation performance
outcomes, such as outage and ignition metrics, customer outage impacts, and operational
lessons learned; results inform future scope to maintain cost-effectiveness over time.
Leveraging existing operations to reduce wildfire risk. CPC works to build on existing processes,
systems, and personnel, when possible, to deploy wildfire mitigation strategies, including by
augmenting existing processes with new technology.
By generally using the process and strategies described above when selecting mitigation
measures to reduce wildfire risk, CPC believes the mitigations identified in this WMP reflect a
reasonable balancing of mitigation costs with the resulting reduction of wildfire risk.
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2026 Wildfire Mitigation Plan

4 CPC's Service Territory and Asset Overview
As part of the risk analysis process, CPC examined its asset locations to identify risks unique to
its service area. This chapter will provide an overview of the service area properties and
associated risks, which are factored into the wildfire mitigation strategy. See Section 1.4 for a
detailed service area description.
Power is provided to CPC members by way of substations, overhead transmission, and sub-
transmission lines, overhead and underground distribution lines. Table 4 depicts a high-level
description of CPC's T&D assets.
Table 4. Asset Description
ASSET ASSET DESCRIPTION
CLASSIFICATION
Approximately 81 miles of conductor, transmission, sub-
Transmission Line Assets transmission structures, and switches at 34.5kV, 69kV and
115kV.
Approximately 2,558 miles of overhead (OH) conductor,
transformers, voltage regulators, capacitors, switches, and
Distribution Line Assets line protective devices operating at 7.2kV and 14.4kV.
Approximately 385 miles of underground (UG) conductor,
sectors, and transformers operating at 7.2kV and 14.4kV.
Major equipment such as power transformers, voltage
Substation Assets regulators, capacitors, reclosers, relays, open-air structures,
switchgear, and control houses in 21 substations.
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2026 Wildfire Mitigation Plan

4.1.1 Wildfire Risk in the Service Area
The fire history map (Figure 2) represents the large fire' history from 2000 through 2020.
Historically, most large fires have occurred in the southern and eastern regions of CPC's service
area. Lightning is the source of approximately 35% of all ignitions, the remainder being human
caused. While lower intensity grass and rangeland fires are more common, in the summer of
2020, forest fires caused by high winds burned over 1,600 acres in the Orofino, Idaho area.
The service area includes a mix of forestland, riparian, and agricultural ecosystems. The most
prevalent vegetated cover type is agricultural land at approximately 28% of the total area.
Although fires in these fuels may not present the same control problems as those associated
with large, high-intensity fires in timber fuel types, they can cause significant damage if
precautionary measures have not taken place prior to a fire event. During extreme drought and
when pushed by high winds, fires in grassland fuel types can exhibit extreme rates of spread,
making suppression difficult. Without substantial fuel breaks between grasslands and forested
areas, grass fires can transition into areas with more volatile fuels.
Ignition potential exists throughout the service area. Recreational areas, major roadways,
debris burning, and agricultural equipment are typically the most common human ignition
sources. The frequency of high wind conditions in North Central Idaho has increased in recent
years, exacerbating the challenges for fire suppression resources.
Miscellaneous
Campfire
Human
Children Fires in
Railroad Idaho, by
Cause
Smoking
Equipment
Use
Arson
Debris Burning
s
' Large Fire as defined by the National Wildland Coordinating Group, is any wildland fire in timber 100 acres or greater,and 300
acres or greater in grasslands/rangelands,or has an Incident Management Team assigned to it.
5 Idaho Firewise 1980-2009
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2026 Wildfire Mitigation Plan

Spokane 14
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Fire History Map 2000-2009 Fire Perimeters N
Service Boundary CPC Distribution A Substation 0 2010-2019 Fire Perimeters
County Boundary CPC Transmission 2020-2024 Fire Perimeters
Sources.Esri,USGS,NOAA
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2026 Wildfire Mitigation Plan

4.1.2 Wildland Urban Interface (WUI)
The United States Forest Service (USFS) defines the WUI as a place where humans and their
development meet or intermix with wildland fuels. The development of wildland areas creates
two problems related to wildfire. First, growth in WUI designated areas results in an increased
chance of wildfire ignitions since electrical power lines must traverse these wildlands to reach
customers. Second, wildfires that occur will pose a greater risk to lives and homes, they will be
hard to fight, and letting natural fires burn becomes impossible.
WUI perimeters were identified and mapped using the data from the United States Department
of Agriculture (USDA) in conjunction with the Spatial Analysis for Conservation and
Sustainability (SILVIS Lab) at the University of Wisconsin-Madison 6. Figure 3 depicts the various
WUI designated areas of CPC's service area. Although the idea of a wildland-urban interface is
easily understood and the term widely used, a specific definition is needed to determine where
it occurs and map its location. The definition we use here is based on a report prepared for the
Council of Western State Foresters on WUI fire risk (Teie and Weatherford 2000) and was later
published in the Federal Register'.
The WUI is composed of both interface and intermix communities. The distinction between
these is based on the characteristics and distribution of houses and wildland vegetation across
the landscape. Intermix WUI refers to areas where housing and wildland vegetation
intermingle, while interface WUI refers to areas where housing is in the vicinity of a large area
of dense wildland vegetation.
The USFS has established five classes of WUI in its assessment:
• WUI Intermix: Areas with >_16 houses per square mile and >_50 percent cover of
wildland vegetation
• WUI Interface: Areas with >_16 houses per square mile and <50 percent cover of
vegetation located <1.5 miles from area >_2 square miles in size that is >_75 percent
vegetated
• Non-WUI Vegetated (no housing): Areas with >_50 percent cover of wildland
vegetation and no houses (e.g., protected areas, steep slopes, mountain tops)
• Non-WUI (very low housing density): Areas with >_50 percent cover of wildland
vegetation and <16 houses per square mile (e.g., dispersed rural housing outside
neighborhoods)
• Non-Vegetated or Agriculture (low and very low housing density): Areas with
<50 percent cover of wildland vegetation and <128 houses per square mile (e.g.,
agricultural lands and pasturelands)
6 http://silvis.forest.wisc.edu/data/wui-change/
7 "Urban wildland interface communities within the vicinity of federal lands that are at high risk from wildfire. Notice."
66. Federal Register 3(2001 January 4): 751-777.
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2026 Wildfire Mitigation Plan

Figure 3. Wildland Urban Interface within CPC Service Area
Spokane
I
County
I
i
I
Benewah
County
t Shoshone
County
--,--------
Whitman '---
County
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Wallowa
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Wildland Urban Interface (WUI) Map
Service Boundary A Substation Interface Grasslands/Pastures No Vegetation;
High Structure Density
County Boundary CWP Lines Intermix Vegetated Rangeland
Esri,HERE,Garmin,SafeGraph,FAO,METIMASA,USGS,Bureau of Land Management,EPA,NPS,Esn,USGS
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2026 Wildfire Mitigation Plan

4.1.3 Fire Threat Assessment Mapping
The Wildfire Hazard Potential (WHP) map is a raster geospatial product produced by the
USDA Forest Service, Fire Modeling Institute that can help to inform evaluations of wildfire
risk or prioritization of fuels management needs across very large landscapes (millions of
acres). The specific objective of the WHP map is to depict the relative potential for wildfire
that would be difficult for suppression resources to contain. The 2024 version was built
upon spatial datasets of wildfire likelihood and intensity generated for the conterminous U.S.
in 2016 with the Large Fire Simulator (FSim), as well as spatial fuels and vegetation data
from LANDFIRE 2012 and point locations of past fire occurrence (ca. 1992 - 2013). Areas
mapped with higher WHP values represent fuels with a higher probability of experiencing
torching, crowning, and other forms of extreme fire behavior under conducive weather
conditions, based primarily on landscape conditions at the end of 20128.
On its own, WHP is not an explicit map of wildfire threat or risk, but when paired with
spatial data depicting highly-valued resources and assets such as communities, structures,
or power lines, it can approximate relative wildfire risk to those resources and assets. WHP
is not a forecast or wildfire outlook for any season as it does not include any information on
current or forecasted weather or fuel moisture conditions. It is instead intended for long-
term strategic planning and as a vegetation/fuels management tool.
To determine fire threat levels within CPC's service area, the electrical system was overlaid on
the WHP maps shown in Figures 4 through 8. The T&D assets as well as substation locations
can be seen in relation to the Hazard Potential Areas (HPAs) shown in color-coded overlays,
which are classified into Low, Moderate, and High hazard areas. Calculations are then
performed using ESRI mapping software to determine the miles of line, based on voltage,
located in the various HPAs. See Table 5 for an overview of this information.
B https://www.fs.usda.gov/rds/archive/Catalog/RDS-2015-0046-2
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Table S. Overview of CPC's T&D Assets within WHIP Tiers*
Line- Line- Line- Line-
Miles Miles s Miles Miles
115 kV OH 4.6 , 0%
Transmission
69 kV OH 40.5 1.9 5% 95% 0.0 0%
Transmission
34.5 kV OH�K 35.1 12.5 36% 22.6 64% 0.0 0%
Transmission
14.4 kV OH 1,683 372.5 22% 985 59% 325.8 19%
Distribution
7.2 kV OH 923.6 300.8 33% 509.5 55% 113.3 12%
Distribution
14.4 kV UG 227.7 57.3 25% 128.4 56% 42 18%
Distribution
7.2 kV UG 133.4 26 19% 89.1 67% 18.3 14%
Distribution
wrp W,
EMMI
Total OH
80.2 19 24% 61.2 76% 0.0 0%
Transmission
Total OH 2,607 673.3 26% 1,495 57% 439.1 17%
Distribution
Total UG 361.1 83.3 23% 217.5 60% 60.3 17%
Distribution
Total Substations 21 10 48% 10 48% 1 5%
*Based on 2024 E&O Mapping Data, which may differ from the 2024 RUS Financial & Operating
Report data used throughout this WMP.
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Figure 4. CPC Service Area and Wildfire Hazard Potential Overview
Spokane County Shoshone
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Whitman
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' Latah
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Clearwater
i I County
i
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Garfield j
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olumbia `
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r
I
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J
Y
Wallowa J ' Idaho
I County County
Oregon Idaho
Wildfire Hazard Potential Overview Map pN
Service Boundary CPC Distribution A Substation Moderate Risk I1
County Boundary CPC Transmission L__� Low Risk High Risk N
Esn,CGIAR,USGS,Sources:Eui,To Tom,Gamin,FAO,NOAA,USGS.,0sen5t,i Om.p conviCutors,and the GIS User
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Figure 5. Wildfire Hazard Potential Map #1
Whitman
County -
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`A Garfield ^y
---
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County Nez Perce
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Columbia
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� LI
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Service Boundary CPC Distribution A Substation Moderate Risk
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Esn,CGIAR,USGS,Sources:Esn,TomTom,Garmin,FAO,NOAA,USGS,,Op StreelMap contributors,and Lhe GIS User CommunRy
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Figure 6. Wildfire Hazard Potential Map #2
Washington Idaho
Benewah
County
I
I
Whitman j
County
Shoshone
County
-
--,--------- - --
J
Latah Clearwater
County County
I
t
I
_ I
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Wildfire Hazard Potential Map ^N
Service Boundary CPC Distribution A Substation Moderate Risk „
County Boundary CPC Transmission 0 Low Risk High Risk N
Esi.CG1AR.USGS.Sources:Esri.To Tom.Gannin.FAO.NOAA.USGS.to Ooen5treeNao mntnbm,and the GIS User Communo
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Figure 7. Wildfire Hazard Potential Map #3
Latah
County
J I ta��
ast Nez National
Historical Historical ParF
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i
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Wildfire Hazard Potential Map qN
— Service Boundary CPC Distribution A Substation Moderate Risk
County Boundary CPC Transmission Low Risk High Risk
Esri,NASA,NGA,USGS,Sources:Esri,TomTom,Garmin,FAO,NOAA,USGS,©OpenStreetMap contributors,and the GIS User Community
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Figure S. Wildfire Hazard Potential Map #4
Latah Clearwater
County County
IT
Whitman
County
1� I
Washington
r
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ounty A ' Nez Perce
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---- Wallowa
a
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1' Historical oa-
Wildfire Hazard Potential Map N
Service Boundary CPC Distribution A Substation Moderate Risk
County Boundary CPC Transmission 0 Low Risk High Risk
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i
1
L
j I
5 Wildfire Prevention Strategy and Programs
CPC has proactively implemented measures to reduce wildfire risks. The WMP outlines existing
fire mitigation efforts and identifies new processes CPC is evaluating or developing.
Generally, the WMP describes specific programs CPC has embarked on to mitigate wildfire risks.
Many of the programs, however, are multi-year and programmatic. While some have an immediate
startup period, full implementation may occur when processes and methods mature.
Several of CPC's current strategies and programs do not fall within any timeframe but remain
situational based on certain events. These conditions are predominantly weather and vegetative fuel-
related and not associated with time periods. Similarly, CPC's emergency preparedness and response
plans, post-incident recovery, restoration, and remediation activities are event-driven and are not
timeframe-dependent. CPC updates these practices as new information emerges and then adopts
improved practices. Furthermore, administrative-related programs such as risk analyses,
performance metrics, and monitoring of this WMP occur at regular intervals. Table 6 depicts the
activities intended to address key wildfire risk factors.
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Table 6. Activities That Address Wildfire Risk Factors
RISK FACTOR MITIGATION MEASURES
• Satellite Imagery of ROW with AI prioritization
• Vegetation Management
SourceFuel Line Inspections
• Right-of-Way Maintenance
• Enhanced Inspection Intervals in High-Risk Areas
INational Weather Service Monitoring
Extreme Weather • Undergrounding of Distribution Lines
• Reduced Span Length in High-Wind Areas
• Wildlife Guards
ContactIncreased Vegetation Clearances
Objects Avian Protection Framing Standards
• Insulated Equipment and Jumpers
• Routine Maintenance
• Focused Design and Construction Standards
Equipment Failure • T&D Line Inspections
• Pole Testing and Treatment
• Infrared Inspections of Substation Equipment
• Monthly Substation Inspections
• Education on Fire Ignition Sources and Fire
Field Work Suppression
• Fire-Watch Services as Required9
• Tailboards
9 Oregon Revised Statute 477.665,629-043-0030
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5.1 T&D Operational Practices
5.1.1 Situational Awareness and Assessment
Situational Assessment is the process by which current operating conditions are determined.
Situational Awareness is the understanding of the working environment, which creates a
foundation for successful decision making and the ability to predict how it might change due to
multiple factors. The CEO and COO or their designees monitor, as needed, the following online
resources to track evolving weather conditions.
• USFS-Wildland Fire Assessment System (WFAS): For immediate and short-term
situational awareness, mapping tools from the USFS-WFAS help determine daily and
short-term forecasted risk. Daily or weekly fire weather status maps are produced as
needed to assess short-term wildfire conditions. (https://www.wfas.net)
• The National Weather Service (NWS): The NWS provides online predictive fire
weather forecasting tools in the form of a current fire-weather outlook, 2-day, and a 3-8
day outlook. (https://www.spc.noaa.gov/products/fire wx/)
• NOAA Weather and Hazards Data Viewer: This online map provides historic or real-
time surface observations including wind speed and direction, wind gust, dew point,
relative humidity, and sea level pressure collected from remote automated weather
stations (RAWS) throughout the northwest. Extreme-weather alerts such as fire weather
watch, high wind watch, and red flag warning are provided from this resource.
(https://www.wrh.noaa.gov/map/?wfo=ps )
• Idaho Wildfire Information: Fire season requirements become effective when fire
season is declared in each Idaho Fire Restriction Area. (http://www.idahofireinfo.com)
• CPC-Owned Weather Stations (pilot program): CPC will evaluate installing its own
weather stations at designated substations throughout the service area. These stations
would be monitored remotely and provide temperature, wind speed, wind direction,
barometric pressure, and relative humidity.
• Washington State Energy Office's Weather Hazards Outlook: Provides an
outlook from all four NWS offices serving Washington State. This product is intended to
supplement normal briefings provided by each office in order to support advanced
planning and decision making. Weather-driven briefings will be provided as usual in
advance of any significant weather events.
During fire season, local TV and radio broadcasts may be monitored in addition to the above
sources.
5.1.2 Industrial Fire Precaution Levels
When conditions of fire hazard exist each summer, the Idaho Department of Lands, United
States Forest Service, or the Bureau of Land Management, (together"Agencies") declare fire
season to be in effect. Title 36 of CFR 261.50(a) gives each Forest Supervisor the authority to
issue orders which close or restrict use of the area over which he/she has jurisdiction. As
conditions warrant, the forester will issue an Industrial Fire Precaution Level10 (IFPL) at one of
10 https://www.oregon.gov/odf/fire/documents/industrial-fire-precaution-levels.pdf
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four levels. Because conditions vary across states, each protection district will declare their fire
season separately. The declaration of fire season affects utility and other commercial operations
and recreational activities by the public. Fire season remains in effect until terminated by each
Agency or by reducing the IFPL until conditions for fire hazard no longer exist. During Fire
Season, the CEO, COO, or their designees shall monitor IFPL levels and direct staff and VM
crews to take necessary precautions and deploy available fire suppression equipment to job
sites as needed.
5.1.3 Fire Precautionary Period
Historically, the North Central Idaho fire season has occurred between June and mid-
September, with mid-August most vulnerable to extreme fire conditions. For this WMP, the Fire
Precautionary Period (FPP) is June 1st to October 1st of each year unless the CEO or COO
deem conditions require starting before June 1st or extending the period beyond October 1st
During this Fire Precautionary Period, CPC and contractor crews shall make reasonable efforts
to:
• Abide by the requirements of this WMP and be responsible for patrolling and preventing
fires caused by operational and VM management activities.
• Take steps necessary to ensure CPC employees, contractors and their employees
prevent ignitions directly or indirectly during their work activities and operations.
• Permit and assist with periodic testing and inspection of required fire equipment.
Operators shall abide by specific fire precautionary measures in this WMP before
beginning operations during the Fire Precautionary Period and shall update such
certification when operations change.
• Prohibit smoking during fire season, except in a barren area or an area cleared to
mineral soil at least three (3) feet in diameter. Under no circumstances shall smoking be
permitted during the Fire Precautionary Period while an employee is operating
equipment or walking or working in grass and woodlands.
• Clear equipment service areas, parking areas, and gas and oil storage areas of
flammable material for a radius of at least 10 feet unless otherwise specified.
5.1.4 Recloser Operational Practices
There are over 530 reclosers on various transmission and distribution lines on CPC's system.
Before line work or clearing operations are performed, reclosers or breakers that have the
capability may be set to the"non-reclose" setting. This setting ensures the recloser or breaker
does not re-energize the line after interrupting a fault while at the same time maintaining
coordination with downstream devices. As of April 2025, CPC has 43 reclosers that will be able
to be remotely controlled when the SCADA system is completed. CPC is currently evaluating the
best strategy for the operation of these units.
5.1.5 Public Safety Power Shutoff
Public Safety Power Shutoffs (PSPS) are strategies used by electric utilities to help keep people
and communities safe during a Red Flag Warning (RFW). A PSPS preemptively de-energizes
selected, at-risk power lines during high-wind events combined with hot and dry weather
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conditions, to reduce or eliminate the risk of CPC-owned assets becoming the origin or
contributing source of an ignition.
CPC considers the external risks and potential consequences of a PSPS while striving to meet its
main priority of protecting the communities and members it serves. These considerations
include but are not limited to:
• Potential loss of water supply from wells and pumping facilities to fight wildfires.
• Negative impacts to emergency response and public safety and health due to disruptions
to the internet and mobile phone service during periods of extended power outages.
• Loss of key community infrastructure and operational efficiency.
• Medical emergencies for members of the community requiring powered medical
equipment or refrigerated medication.
• Negative impacts on medical facilities.
• Negative economic impacts from local businesses forced to close.
• The inability to open garage doors or motorized gates.
• Timeframe to patrol and re-energize distribution circuits that have been subject to a
PSPS.
The risks and potential consequences of initiating a PSPS are significant and extremely complex.
Based on the above considerations, CPC reserves the option of implementing a PSPS when
conditions dictate. While CPC believes the risks of implementing a PSPS far outweigh the
chances of its electric overhead distribution system igniting a catastrophic wildfire, the PSPS
may provide a last resort option to avoid a possible ignition involving CPC assets.
On a case-by-case basis, CPC has historically and will continue to consider de-energizing a
portion of its system in response to a request from an outside emergency management agency.
If conditions on the ground indicate that a wildfire threat is imminent, CPC's CEO or the COO if
the CEO is not available, has the authority to de-energize select transmission and distribution
circuits. A decision is based on multiple factors accompanied with the unique understanding of
the CPC system, including any risks involved. No single element is determinative. CPC relies on
weather data from various sources, including the National Weather Service, NDFRS, and the
USFS Wildfire Assessment System, as well as on the ground observations from field personnel.
5.1.6 Strategy for Re-energization
When fire risk conditions return to safe levels and conditions are verified, CPC will patrol
impacted circuits to confirm that no conditions exist that could potentially present a public
safety hazard when re-energizing circuits. Once CPC confirms that it is safe to re-energize the
affected circuits, power will be restored, and local government and members will be notified of
re-energization status as needed.
5.2 Infrastructure Inspections and Maintenance
Recognizing the hazards of equipment that operate high-voltage lines, CPC maintains a formal
inspection and maintenance program for distribution, transmission, and substation equipment.
The COO oversees the time-based system inspection programs and the wood pole inspection
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program. CPC currently patrols its system at regular intervals. Table 7 summarizes the
inspection schedule for all assets, while the following plan sections outline inspection practices
for the utility.
For the portion of CPC's service area located in the State of Oregon, CPC follows Oregon
Administrative Rules (OAR) Chapter 860-024-0011, which provides inspection schedule
requirements for electric distribution and transmission assets.
Table 7. Inspection Cycles
ASSET INSPECTION TYPE 140
CLASSIFICATION
Line Patrol Every 2 years
Overhead Detailed Inspection Every 15 years*
Pole Test and Treatment Every 15 years
Line Patrol Every 2 years
Overhead Detailed Inspection Once every 15 years*
Pole Test and Treatment Every 15 years
Line Patrol Once every 2 years
Underground
Detailed Inspection Every 15 years*
Routine Inspection Monthly
Substations
* Every 10 years for lines located in Oregon
5.2.1 Definition of Inspection Types
1. Line Patrol: A simple visual inspection of utility equipment and structures designed to
identify hazards.
2. Detailed Inspection: Utility equipment and structures receive a detailed visual
examination and may include using diagnostic testing procedures.
3. Pole Test and Treatment: CPC contracts with a third-party to test and treat wood
poles on a rotating basis.
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5.2.2 Instructions to Inspectors
CPC considers and prioritizes maintenance work by assessing the most urgent needs. The
inspection should focus on hazards that could affect the system's integrity or the safety of
workers and the public. The inspector will document the inspection data and prioritize any
deficiencies as follows:
• Priority #1 — Immediate hazard: A deficiency posing imminent danger to life or
property must be repaired, disconnected, or isolated immediately after its discovery.
Also, any conditions that may affect the system's integrity or present a hazard to line
workers or the public pose an immediate hazard. Priority #1 repairs will be responded
to immediately, and appropriate action taken until the hazardous condition is remedied.
• Priority #2 — Non-emergency repair condition: Except as otherwise provided,
deficiencies should be corrected no later than two (2) years after discovery. These are
conditions requiring maintenance, which can be scheduled to maintain the system's
integrity. Repairs will be prioritized by urgency and scheduled to have appropriate
repairs to correct the condition.
• Priority #3 — Non-emergency repair condition: CPC may elect to defer correction of
deficiencies that pose little or no foreseeable risk of danger to life or property to
correction during the next major work activity. Includes conditions that do not
jeopardize the system's safety, line workers, and the public. Repairs are completed
within the time interval recommended.
5.2.3 Line Patrol
CPC has a line patrol procedure that complies with OAR 860-024-0011 and NESC requirements
that includes bi-annual inspections of CPC assets. The maximum interval between line patrols
is two (2) years, with a recommended rate of 50 percent of assets per year. CPC personnel
look for visible signs of defects, structural damage, broken hardware, displaced lines, and
vegetation clearance issues. Any anomalies found are addressed based on the severity of the
defect. Efforts are made by line crews to identify and document hazard trees during line
patrols. Areas identified as "High" risk for wildfire are patrolled annually before fire season.
5.2.4 Detailed Transmission & Distribution Inspections
Detailed inspections of the transmission and distribution system are conducted on a fifteen (15)
year cycle. Assets located in the State of Oregon are given detailed inspections every ten (10)
years per OPUC requirements. Inspections and maintenance activities are intended to protect
the worker, the public, and the system's reliability based on current industry standards.
System equipment found in need of maintenance or repair is categorized depending on the
severity of the condition. A record of the inspections and maintenance performed will be made
available to regulators when requested and maintained by the appropriate personnel. The
maximum interval between detailed inspections of overhead and underground assets is fifteen
(15) years.
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Detailed Line Inspections (DLI) consist of walking and driving to examine CPC poles,
conductors, and equipment. Detailed inspections of assets include, but are not limited to:
• Mechanical damage
• Broken or loose hardware
• Guy wire and anchor condition
• Disconnects and fuse holder condition
• Insulators and conductor condition
• Condition of transformers and reclosers
• Ground conductors
• Pole numbers and other minor hardware
• Raptor nests
• Wood rot
• Fire damage
• Third-party attachments
5.2.5 Wood Pole Test and Treatment
The pole inspection work is performed by a third-party contractor that specializes in wood pole
inspection and overseen by CPC's COO. This inspection work is performed and tracked using
pole inspection software. CPC has over 50,000 wood poles in its system and inspects
approximately 6.6% annually. Less than 3% of the inspected poles are rejected annually, due
mostly to shell rot. This inspection interval is in line with RUS Bulletin 1730B-121 regarding
wood pole inspection and maintenance practices.
5.2.6 Substation Inspections
During substation inspections, individual pieces of equipment and or structures receive a visual
examination and routine diagnostic testing as appropriate. Substation inspections occur
monthly, and transformer oil testing is performed annually.
Substation inspection involves a thorough look at the system to confirm that there are no
structural or mechanical deficiencies, hazards, or tree trimming requirements. Inspections of
substations include, but are not limited to:
• Broken or loose hardware
• Vandalism or damage to any equipment
• Oil or gas leaks
• Condition of the bus
• Insulators and other hardware
• Condition of the control house
• Condition of the poles/structures and lines exiting the substation
• Condition of the disconnects and fuses for signs of damage and connectivity
• Insulators, bushings, and arrestors
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• Risers and conduits
• Transformers
• Reclosers
• Batteries
• Capacitors
• Circuit breakers
• Fire detection and suppression system (where applicable)
• Grounding
• Voltage regulators or tap changers
• Perimeter fence security
• Lighting and security cameras
5.2.7 Standards for Record-Keeping and Reporting
General Instructions: Facilities meeting standards and not requiring maintenance will be
recorded and stored for future reference. Conditions other than satisfactory go into CPC's asset
management database, and the COO or their designee generates a list of deficiencies and
monitors the completion of repair work. CPC maintains adequate written records to show
inspections and corrective actions meet compliance with relevant state code.
5.2.8 GIS Mapping
CPC uses a network of physical facilities to provide electric power and energy to members
connected to those facilities throughout a geographical area. Each component of the
distribution system and each meter have an approximate physical location and associated
data. To plan, construct, maintain, and operate the distribution network it is necessary to
create, manage and utilize this geospatial data.
CPC geolocates and manages its assets utilizing National Information Solutions Cooperative
(NISC) MapWise software and has integrated this technology into its inspection and
maintenance program, as well as for tracking VM work. This provides the ability to record and
map inspections, service work, and tree trimming to ensure work is performed on a prescribed
schedule.
5.3 Vegetation Management
State and Federal Agencies require maintenance of CPC's right-of-way under or around power
lines. CPC has developed a comprehensive VM program intended to maintain safe and reliable
electric facilities throughout the service area. The COO or their designee oversees the VM
program.
CPC's right-of-way is primarily located on privately-owned property however, a small portion
crosses State and Federal land. Roughly 30%, or 900 miles, of CPC's overhead lines are in
wooded areas and require right-of-way maintenance.
The topography is diverse and can be categorized into three types: river valleys and canyon
bottoms; bench lands or prairie; and timbered mountains. Parts of the distribution system are
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aligned along rural roadways, but many miles are routed directly across dryland farms, steep
river breaks, and heavily treed landscapes.
5.4 T&D System Vegetation Management Overview
To minimize the interruption of electric service from power line contact and to permit
equipment access to service power lines, CPC maintains a systematic right-of-way VM policy.
CPC's goal is to work by substation, feeder, and line section on an approximate ten-year cycle.
This approximates to 90 miles of power line right-of-way clearing per year and is completed
with CPC personnel as well as third-party contractors.
CPC's service area is divided into three (3) "Districts". Areas for VM work are identified in
advance, based on determinations and recommendations made by the foreman and serviceman
in each District. Although growth rates are similar throughout the service area, rapid growth
areas do occur and are given priority for clearance work before the systematic trimming of
circuits.
Assets are geolocated in ArcMap and mapped using NISC MapWise software. The MapWise
tools allow CPC to map the areas trimmed and verified to ensure lines are inspected and
trimmed per the prescribed schedule. The MapWise system allows for enhanced work order
management and VM progress tracking. The right-of-way tool also allows for notes and
classification by type of clearing.
The employee tasked to track the contractors' work, is responsible for inspecting the right-of-
way clearing and reporting the contractor progress to the Engineering Department to input in
MapWise. This is also used to approve the billing process.
5.4.1 Vegetation Management Trimming Standards
Pruning shall be performed with consideration given to the impact on reliability, individual tree
condition, and tree aesthetics.
CPC crews follow standard practices for safety", reliability, policies, procedures, and
compliance with the National Electric Safety Code (NESC)12, RUS, and relevant state and federal
requirements.13. Work performed to these guidelines provides reasonable service continuity and
guards against wildfire damage caused by supply conductors.
5.4.2 Vegetation to Conductor Clearance Guidelines
Trees or vegetation encroaching power lines are trimmed or removed as needed to maintain the
necessary minimum clearance distances within the power line right-of-way. Where complete
removal cannot be accomplished, trees will be trimmed to maintain the scheduled interval. CPC
follows RUS14 specifications for right-of-way maintenance (Figure 9). CPC's line clearing work
11 OSHA 1910.269 training requirements
12 Rules 012,013 and 218
13 Specification Applicable to VM work in Oregon State. OPUC OAR 860.024.0016/0017
14 Rural Utilities Service https://www.rd.usda.gov/about-rd/agencies/rural-utilities-service
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meets minimum standards for conductor clearances from vegetation to provide safety for the
public and line workers, reasonable service continuity, and fire prevention. The tree's location,
health, species, and growth rate is considered when deciding whether clearance greater than
the minimum is needed.
In determining the extent of trimming required to maintain the clearances required by the NESC
and RUS, CPC considers at minimum the following factors:
• Voltage;
• Location;
• Configuration;
• Sag of conductors at elevated temperatures and under wind and ice loading; and
• Growth habit, strength, and health of vegetation growing adjacent to the conductor,
with the combined displacement of the vegetation, supporting structures, and
conductors under adverse weather or routine wind conditions.
The VM program aims to achieve the clearance specifications illustrated in Figure 9.
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Figure 9. Vegetation to Conductor Clearance
RI-30
15'-0" 15'-0" �
min. min.
ELEVATION
1 ,
J G
BEFORE CLEARING
VA
AFTER CLEARING
3 Phase and B Phase Primary
CLEARING RIGHT-OF-WAY GUIDE
,AN 1,1962 RI-30
5.4.3 Vegetation Control Methods
One or more of the following VM methods may be used at CPC's discretion depending on the
vegetation mix. The method will be determined by CPC and/or its contractor.
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• Complete removal of trees or vegetation in the right-of-way. Brush mowing.
• Foliar spraying with certified applicator using approved products.
• Trimming back trees following minimum clearance guidelines and industry practices.
• Allowing low-growing vegetation that allows walking through the right-of-way to remain.
Thorny brush and other difficult-to-pass-through vegetation will be removed.
• Replacing overhead line with underground to eliminate future VM.
When conditions allow, overhead lines aay be converted to underground at CPC's discretion.
The member or landowner will be responsible for the costs based on the applicable policy.
5.4.4 At-Risk Vegetation
Although CPC employs a systematic trimming policy, when conducting routine maintenance of
power lines and related equipment, CPC makes efforts to identify and remove high-risk fuel
sources as needed. Service orders will be created in response to an employee recognized
hazard to trim or remove trees threatening power lines when not in the regular trimming cycle.
Depending on the severity of the hazard, the tree may need to be removed immediately.
5.4.5 Member Requests
Service orders, as required, are created in response to member or landowner requests to trim
or remove trees threatening power lines when not in the regular trimming cycle. CPC or its
contractor will communicate with member or landowner regarding the request. After trimming
or tree removal, the member or landowner is responsible for clean-up except in circumstances
as determined by CPC or its contractor. Member requests will be satisfied on a timeline that is
most economic to CPC and considering the severity of the hazard and safety of the public. CPC
reserves the right to refuse to cut or remove any tree which, in its judgment, can be safely cut
or removed by a private tree company with no damage to CPC's lines.
5.4.6 Member-Owned Lines
CPC is not responsible for trimming or removal of trees endangering the property owner's lines
located beyond the point of metering. At the member/landowner's request, CPC will de-
energize lines so trimming or tree removal can be done safely.
5.4.7 Storm Damage
Storm damaged trees will be cut and trimmed to correct hazardous situations and to allow for
repair of electric lines. Clean up is the responsibility of the member/landowner.
5.4.8 Clear Cut Right-of-Way Specifications
Stumps are cut as close and parallel to the ground level as possible to not leave a 'spike" or
angle cut stump in the right-of-way, which can damage tires or equipment.
5.4.9 Tools and Equipment
CPC owns and maintains three (3) 150-gallon and one (1) 200-gallon water tanks with pump
and hoses mounted on trucks for fire suppression during the FPP. In addition, fire suppression
tools, including water backpacks, shovels and/or fire rakes, are available on vehicles and at
operating sites. Crews conduct tailboard meetings to confirm the location and readiness of the
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fire suppression equipment. If required, fire-watch will remain on site for up to three (3) hours
to ensure a fire doesn't start after crews leave a remote or high-risk area. The COO monitors
weather conditions and RFW.
5.5 Fire Mitigation Construction
CPC is taking steps to harden the electrical system with upgrades and design changes. These
designs stem from engineering experience and the adoption of emerging technologies. CPC's
design practices continue to advance with the addition of newer safety and reliability-related
technologies. This advancement recognizes the importance of understanding and adapting to
the challenges brought on by the use of public land, development in the WUI, and climate
change. The following sections describe these projects.
5.5.1 Wood Pole Fire Protection
The topography of CPC's service area is very challenging. It is especially difficult when it comes
to the installation and replacement of wood poles. Many of CPC's poles are located in areas
both susceptible to naturally occurring wildfire, and difficult to access with the equipment
required for pole replacement. CPC has had success with the application of a fire-resistant
coating or mesh designed to protect wood utility poles from fire damage. These products have
saved the utility time and money on pole replacement work over the past fifteen (15) years. An
example of these benefits is shown in Figure 10.
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Figure 10. Treated Pole
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5.5.2 Avian Protection Construction Standards
Since 2000, CPC has employed design and construction standards in accordance with RUS avian
protection standards. These include the use of perches, longer crossarms and lowering the
placement of crossarms on the poles to increase the distance between phases and/or neutrals.
These measures have reduced the electrocution risk to raptors and the number of raptors that have
been injured. Consequently, these measures have reduced the risk of fire ignitions. New
construction, as well as rebuilds, are evaluated for the use of RUS avian protection standards.
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Wildlife protective devices are installed on substation equipment in addition to poles. The following
measures have been implemented as design allows:
• Raptor framing
• Insulated jumpers and equipment
• Wildlife protective guards
• Nesting platforms adjacent to structures
• Fiberglass crossarms
• Increased phase and/or neutral spacing
At locations where a bird has been harmed, the pole and equipment are evaluated for
reconfiguration to mitigate any future incidents in accordance with RUS avian protection standards.
A typical installation of avian protection on a distribution structure is shown in Figure 11. The
elevated nesting box provides a safe place for raptors to construct their nests away from energized
equipment.
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Figure 11. Avian Protection Construction
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5.5.3 Underground Conductor
The undergrounding of overhead distribution lines eliminates the impacts of ice loading,
improves reliability in high wind and functions as an effective wildfire mitigation strategy. CPC
has approximately 385 miles of 7.2 kV and 14.4kV UG distribution line in its system and will
continue to evaluate undergrounding conductors in heavily forested and high fire-risk areas.
While there are many benefits to undergrounding distribution lines, these facilities take longer
and cost significantly more to construct, maintain, and repair.
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5.6 Pilot Projects
CPC plans to initiate various pilot projects to explore new technologies and best utility
practices. These pilot projects will serve to evaluate the effectiveness of new technologies
while controlling unwarranted expenditures on unproven methods. CPC may elect to integrate
these technologies or practices into its ongoing maintenance programs based on the
outcomes.
5.6.1 Electronic Reclosers with Remote Adjustability
CPC currently has 35 G&W Viper reclosers with SEL electronic relay controls in use and is
adding additional units. Remotely configuring these relays to"non-reclose"during weather
events may reduce the potential for ignition and is currently being evaluated.
5.6.2 Non-expulsion Fuses
Typical utility industry practice is to install expulsion fuses on tap-lines as a means of
protecting and isolating parts of the system that have experienced a faulted condition.
Expulsion fuses utilize a tin or silver-link element in an arc-tube that expel gas and
potentially molten metal to the atmosphere as a means of extinguishing an arc created by a
faulted condition. The molten metal, however, can be a source of ignition for fire. Non-
expulsion current-limiting fuses are a non-venting fuse encapsulated within a tube to contain
the arc and gases, which minimizes the potential for molten metals to be expelled. CPC is
investigating the use of non-expulsion fuses in some locations where benefits of this
technology can be attained in select elevated fire risk areas.
5.6.3 Drone Inspection Program
Due to the challenging terrain that makes up the service area, CPC has acquired drone
technology to enhance its asset inspection and VM programs. The drone is equipped with a
high-resolution camera allowing for detailed inspections of crossarms, hardware and
equipment not visible from the ground. The VM program would benefit as well, as this
technology would expedite inspection cycles and hazard tree identification, especially in the
areas with limited access and steep terrain. The drone is also fitted with infrared imaging
technology, which will be used to identify problem areas.
5.6.4 Satellite Imaging Program
CPC is contracting with a third-party company to use satellite imagery to scan the ROW in high
WHP areas and create a 3-D model. The imagery is then run through their proprietary AI
algorithms to prioritize vegetation management by circuit. This will allow CPC to dispatch VM
crews to the highest priority circuits first. This should reduce the chance of wildfire ignition in
these areas and increase the efficiency of VM crews, allowing for more ROW to be maintained.
5.6.5 Weather Stations
As part of its proactive approach to improve CPC's situational awareness capabilities, CPC is
investigating the options for the installation of weather stations in substations located in high-
risk areas. Weather station observations would allow the Operations Department to analyze
critical fire weather elements at critical locations in real time. Since the service area is quite
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expansive, having the ability to collect precise weather information will allow the utility to
focus its attention and resources on the areas showing the most immediate risk. High
resolution cameras are another optional feature available on some stations. Most systems
typically measure the following parameters:
• Air temperature
• Relative humidity
• Wind speed
• Wind direction
• Precipitation
• Barometric pressure
• Solar radiation—sun plus sky radiation
5.7 Workforce Training
CPC has developed rules and complementary training programs for its workforce to reduce the
likelihood of an ignition. Field staff are:
• Trained on the content of the WMP
• Trained in proper use and storage of fire extinguishers
• Required, during pre-job briefings, to discuss the potential(s) for ignition, environmental
conditions (current and forecasted weather that coincides with the duration of work for
the day)
• Required to identify the closest fire extinguisher and other fire abatement tools
• Required to report all ignition events to the COO for follow-up
• Encouraged to identify deficiencies in the WMP and bring such information to the COO.
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6 Emergency Response
6.1 Preparedness and Response Planning
CPC has taken efforts to identify and coordinate with stakeholders in its service area. The
following sections describe emergency planning,jurisdictional structure, and community
outreach efforts.
6.1.1 Emergency Restoration Plan
Electric utilities that borrow from the RUS are required to conduct a Vulnerability and Risk
Assessment of their entire electric system and business 15. Results of this study are then
incorporated into an Emergency Restoration Plan (ERP). The development of an ERP offers a
utility the opportunity to prepare and plan the most efficient means in which to restore its
system in the event of either a small, isolated outage or a system wide outage resulting from a
major natural disaster or other cause. A coordinated response will then be developed to
restore critical resources in a timely and rational manner, to allow for effective response to the
emergency leading to restoration of services and business functions.
Mission and objective of the ERP:
To establish defined responsibilities, actions, and procedures to recover CPC electrical and
communications system in the event of an unexpected and unscheduled interruption. The ERP
is structured to attain the following objectives:
is Section 1730.26 (b)
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• Restore the physical network within the critical time frames established and accepted by
management.
• Restore the applications within the critical time frames established and accepted by
management.
• Restore the nominal course of cooperative business operations within the critical time
frames established and accepted by management.
• Minimize the impact on the cooperative and members with respect to dollar losses and
operational interference.
Information included in CPC's ERP:
• A list of key contacts.
• A list of key federal emergency response numbers.
• A list of key utility management and other personnel and identification of a chain of
command and delegation of authority and responsibility.
• Procedures for recovery from loss of power to the headquarters, key offices, and/or
operation center facilities.
• A business continuity section describing a plan to maintain or re-establish business
operations following an event.
• Mutual aid agreements.
Title 7 CFR Part 1730 requires RUS borrowers to exercise their ERP at least annually to ensure
operability and employee familiarity with the ERP. CPC may exercise the ERP in several ways:
• After an event that requires CPC to utilize a portion of the ERP.
• Participate in joint exercises with other utilities, with other borrows, or State or County
Agencies.
• Performing a tabletop exercise.
CPC's Incident Commander for all emergencies is the CEO. Roles of the Emergency Restoration
Team will be defined in the ERP document. CPC will conduct annual exercises of the ERP,
document the results, and implement lessons learned. Procedures for the development of the
ERP can be found in RUS Guide 173013-2.
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6.1.2 Government Agency Land Partners
The following describes the various stakeholders or districts with management responsibilities
within CPC's service area.
Idaho State: Benewah County, Clearwater County, Idaho County, Latah County, Lewis County,
Nez Perce County, and Shoshone County
Oregon State: Wallowa County
Washington State: Asotin County, Garfield County, and Whitman County
National Forests: Idaho Panhandle National Forest, Nez Perce National Forest, Umatilla
National Forest, and Wallowa-Whitman National Forest
Department of the Interior: Bureau of Land Management, Bureau of Indian Affairs
Tribal Lands: Coeur d'Alene Reservation and Nez Perce Reservation
Land Management is illustrated in Figure 12.
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Figure 12. General Land Management
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6.1.3 Emergency Management Communication and Coordination
In response to active emergencies, CPC coordinates and collaborates with local Departments of
Emergency Management (DEM) and relevant state agencies as needed. During such emergencies,
CPC provides a utility representative to the DEM, as requested, to ensure effective communication
and coordination. CPC's primary coordination point is Nez Perce County Emergency Management
Department (EMD). The COO or their designee will contact the EMD to coordinate responses as
required and will serve as the communications officer during an emergency.
6.1.4 Fire Response and Suppression Capabilities
On wildland fires, fire districts typically provide initial attack resources until the Idaho
Department of Lands assumes command of the incident.
Clearwater County Sheriff's Office (CCSO) provides dispatch services for first responding
agencies and, during the summer also notifies Clearwater-Potlatch Timber Protection
Association (C-PTPA) of wildfire issues in Clearwater County. In addition, CCSO can
communicate with the surrounding fire departments and State Police via UHF radio located in
the dispatch center. CCSO utilizes the State Communications Center, which can patch
communication lines for CCSO to other agencies throughout the State of Idaho.
Mutual aid agreements have been made between each of the local fire districts and the Idaho
Department of Lands to supplement resources of a fire agency or district during a time of
critical need.
Figure 13 depicts the fire districts throughout CPC's service area. As shown, there are
unincorporated areas that are not currently protected by any fire district. These areas are
protected by Idaho Department of Lands (IDL), US Forest Service (USFS), Washingon
Department of Natural Resources (WADNR), or the Oregon Department of Forestry (ODF).
The following fire suppression agency acronyms are used in Figure 13:
CVPD = County Fire Protection District
FD = Fire Department
RFPA = Rangeland Fire Protection Associations
RFPD = Rural Fire Protection District Fire Protection District
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Figure 13. Fire Protection District Map
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6.2 Community Outreach
Public outreach with the community on the importance of wildfire mitigation helps to reduce risk
and can play a significant role. CPC encourages its members to take proactive steps to
safeguard their homes from wildfire danger and prepare for emergency events. To help create
an awareness of fire danger in the service area, CPC provides information on prevention and
safety in its Ruralite Magazine, website, bill stuffer publications and social media.
Members can find useful information regarding:
• Defensible Space Guidelines
• National Weather Service Alerts
• Fire Season Preparation
• Emergency Planning
6.2.1 Public Agency and Member Communications for Outages
For scheduled outages, CPC provides as much advance notice as possible, depending on the
number of members impacted. Depending on the scope of the project and the length of time
prior to the outage, members receive automated telephone calls using NISC's Multi-Channel
Messenger module advising of the outage. For larger scheduled outages, information is also
posted on CPC's Facebook page and website.
For large unplanned outages, information regarding the number of members affected and
geographical location are posted on social media and CPC's webpage. The COO or their designee
makes the decisions on when and how to issue public announcements.
6.3 Restoration of Service
After unplanned outages during fire season, whether due to a PSPS or unknown causes, CPC
personnel will patrol the affected portions of the system before the system is re-energized.
Suspect equipment or distribution lines that cannot immediately be patrolled will remain de-
energized until CPC personnel can do so. System components included in an unplanned outage
or PSPS must be assessed and repaired as needed prior to re-energization. Periodic member
and media updates of restoration status prior to full restoration will be made.
6.3.1 Service Restoration Process
After a wide-spread outage, CPC line crews take the following steps before restoring electrical
service. These measures intend to protect the worker, members, the public, and the system's
reliability.
• Patrol: Crews patrol de-energized lines to ensure no hazards have affected the system
during the outage. If an outage is due to wildfire or other natural disasters, as soon as it
is deemed safe by the appropriate officials, crews inspect lines and equipment for
damage and estimate equipment needed for repair and restoration. Lines located in
remote and rugged terrain with limited access may require additional time for
inspection.
• Isolate: Isolate the outage and restore power to areas not affected.
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• Repair: After the initial assessment, CPC personnel, including but not limited to,
Operations, Engineering, and Management meet to plan the needed work. Rebuilding
commences as soon as the affected areas become safe. Repair plans prioritize
substations and transmission assets, then distribution circuits serving the most critical
infrastructure needs. While the goal to re-energize all areas is as soon as possible,
emergency services, medical facilities, and utilities receive first consideration when
resources are limited. Additional crews and equipment are dispatched as necessary.
• Restore: Periodic member and media updates of restoration status before full
restoration are posted on social media and CPC's website. After repairs are made, power
is restored to homes and businesses as quickly as possible. Members, local news, and
other agencies receive notification of restored electric service as needed.
The general priority order for restoration work is as follows:
1. Transmission lines
2. Substations
3. Main distribution feeders
4. Secondary distribution feeders
5. Services
7 Performance Metrics and Monitoring
CPC has developed performance metrics (See Table 8) to provide a data-driven evaluation of
the WMP's performance to help determine the effectiveness of various programs and to
identify areas for improvement.
This chapter also identifies CPC's management responsibilities for overseeing this WMP and
includes the operating departments and teams responsible for carrying out the various
activities described in the previous chapters. Methods for identifying plan deficiencies are
discussed along with inspection and VM program monitoring processes.
7.1 Plan Accountability
The Board of Directors makes policy decisions relative to CPC and they will be responsible for
approving the WMP.
The CEO and the COO are responsible for the overall execution the WMP. Staff will be directed
as to their roles and responsibilities. The COO or their designee is also responsible for
communicating with the public, media outlets, public agencies, first responders, and local
Emergency Management during an emergency or planned maintenance outages. The CEO and
COO determine when and how to notify outside agencies in cases of wildfire emergency
events.
7.2 Monitoring and Auditing of the WMP
CPC's CEO will be responsible for monitoring and auditing the targets specified in the WMP to
confirm that the objectives of the WMP are met, as well as the implementation of the WMP in
general. Reports of the WMP's progress and risk reduction impacts will be developed annually
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and circulated to appropriate utility staff along with recommendations or proposed actions to
enhance the WMP's objectives and strategies over time. The effectiveness of the WMP will be
reported to the Board of Directors on an annual basis.
7.2.1 Revising the WMP
The CEO and COO are responsible for ensuring the WMP meets Idaho, Oregon, and Washington
requirements related to WMPs. CPC Staff responsible for assigned mitigation areas should vet
current procedures and recommend changes or enhancements to build upon the WMP's
strategies. Due to unforeseen circumstances, regulatory changes, emerging technologies, or
other enhancements in the WMP may be warranted or required. The WMP will be updated as
needed to correct issues and incorporate new guidelines and best practices. Updates to the
WMP will be tracked.
7.3 Performance Metrics
CPC has selected several metrics (Table 8) intended to gauge the effectiveness of the
various programs and strategies outlined in the WMP.
The continual tracking of these metrics will help identify circuits most susceptible to
unexpected outages, ignition risks, and the adequacy of the VM and asset inspection
schedules. CPC will reassess its operations and identify areas for improvement as more data
becomes available and refine the WMP as needed.
As results of CPC's mitigation programs become evident and additional data is collected, CPC
will identify areas of its operations that will require updating. As the metrics are analyzed in
the following years, refinements will be made to the WMP. The selected metrics, as with
other aspects of the WMP, will likely evolve in future iterations of the WMP.
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Table S. Performance Metrics
Metric Rational Indicator Measure of
Effectiveness
Red Flag Warning Used to adjust annual Number of RFWs
(RFW) days variation in criteria during analysis N/A
cycle
Ignitions in High WHP
Assess system hardening Reduction or no
tier involving CPC Count of events
efforts in critical areas material increase
assets
Service interruption Assess system hardening Reduction in the
with fire reference efforts Count of events general trend of
events
Outages due to line Assess VM program work Number of Reduction in the
contact with schedules/QC process contacts recorded general trend of
vegetation or animals events
Vegetation or animal Assess VM program work Count of events Reduction or no
caused ignition schedules/QC process material increase
Member service calls Assess if VM Program has Number of calls Reduction in the
concerning at risk reduced member customer received general trend of
vegetation concerns and risk events events
Power line down in
Reduction in the
High WHP area during Assess system hardening
Count of events general trend of
the Fire Precautionary efforts in critical areas
events
Period
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a F
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7.4 Programmatic Quality Assurance/Quality Control processes
7.4.1 T&D System Inspection QC Process
The COO manages the T&D line and substation assets including pole inspection and
comprehensive equipment and ROW maintenance programs. The COO also manages design
and inspection of new construction. These programs ensure proper design and safe operation
of the T&D line and substation assets.
Key imperatives are to:
• Reduce the risk of power-related wildfire.
• Meet federal and state regulatory requirements.
• Achieve reliability performance within mandated limits and to optimize capital and 0&M
investments.
Designated managers regularly monitor inspection and corrective maintenance records and
diagnostic test results to adjust maintenance plans and develop new programs. CPC follows
prudent utility practices to develop its maintenance programs.
CPC's Engineering and Operations departments are responsible for performing the
inspections and corrective maintenance. The priority for corrective maintenance is to
remove safety hazards immediately and repair minor deficiencies according to the type of
defect, severity of the risk level associated with the location of the asset. The process is
monitored throughout the year to ensure timely completion via regular internal reports.
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7.4.2 Vegetation Management QC Process
Contractor crews perform the majority of VM and clearing work for the utility. Contracted VM
work is field audited by CPC personnel. Quality control efforts monitor program effectiveness,
overall tree work performance, and determine the adequacy of the VM work schedule. CPC's
right-of-way clearing work is tracked using NISC GIS mapping software. The quality control
results are reviewed, and any deficient work is reissued to the contractor for corrective action.
4
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Appendix A: Disclaimers
WMP MAPPING DISCLAIMER
Maps in this report were created from multiple datasets from various public and private sector
sources and may include utility Geographic Information System (GIS) data. The geographic
information contained in the map(s) is not to be used as a "legal description" or for any purpose
other than general planning and reference. Every effort has been made to ensure the accuracy
of the map(s), but errors in source documents do occur and inherent mapping ambiguities are
not shown.
Maps are for information purposes only and may not represent actual current conditions. CPC,
including, without limitation, its employees, agents, representatives, officers, and directors, may
not be held responsible or liable in any way for any information and/or data, or lack thereof,
provided in the map(s).
CPC-produced maps are not to be copied or distributed without written permission.
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Appendix B: Glossary
Term Definition
ArcMap Esri's classic desktop Geographic Information System software, used for
viewing, editing, analyzing and mapping spatial data.
Artificial Intellengence (AI) The simulation of human intelligence in machines, enabling them to learn,
reason, perceive, solve problems, and understand language to perform
tasks.
Avian Protection Standards Guidelines and regulations, based on U.S. federal laws, focused on
minimizing bird harm (collisions, electrocutions) from infrastructure like
power lines.
Capacitors A simple electronic component that stores electrical energy in an electric
field, acting like a tiny, fast-acting battery that charges and discharges
quickly.
Clear Cut Specifications Rules for clearcutting forests or removing vegetation completely from
rights-of-way.
Clearance Guidelines Requirements for the minimum distance between vegetation and power
lines.
Control Houses Prefabricated, customizable buildings that contain critical electrical gear,
automation systems, and power distribution equipment.
Crossarms Horizontal structural supports mounted on top of utility poles, acting as
crucial components for holding power lines, insulators, and other
equipment at safe distances.
Defensible Space Area around structures cleared to reduce fire risk.
Distribution Lines Lower-voltage lines (typically 4 kV to 25 kV) that deliver electricity to
homes and businesses.
Drone Inspection Program Use of drones for inspecting power lines and vegetation.
Electrical Grid (Grid) A vast, interconnected network that generates, transmits, and distributes
electricity from power plants to consumers.
Electrical System A network of components that supply, transfer, and use electric power,
with the electrical grid being a prime example.
Emergency Restoration Plan (ERP) Procedures for restoring power after disasters.
Esri A mapping technology company that produces powerful mapping and
spatial analytics technology.
Foliar Spraying Applying herbicide to leaves for vegetation control.
A popular line of solid dielectric, electronically controlled reclosers from
G&W Electric used for overcurrent protection and automation in electrical
G&W Viper distribution systems.
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Geographic Information Systems Geographic Information System for asset and vegetation tracking.
(GIS) Mapping
Hazard Potential Areas (HPAs) Zones classified as Low, Moderate, or High fire risk.
Infared Inspections Using thermal imaging to detect heat patterns, revealing hidden problems
like overheating electrical connections, moisture intrusion, and insulation
gaps in buildings, machinery and electrical systems.
Jumpers A short length of electric conductor used to make a connection. For
example, connecting an overhead powerline to an overhead transformer
bushing.
Large Fire Simulator (LFSim) Simulates the growth and behavior of hundreds of thousands of fire
events for risk analysis across large land areas using geospatial data.
Line Patrols In person or drone inspection of power line by journeymen linemen.
Main Distribtuion Feeders High-voltage power lines carrying electricity from substations to local
areas.
Mutual Aid Agreements Contracts for sharing resources during emergencies.
National Electric Safety Code (NESC) Industry rules for safe electrical system design and operation.
National Electrical Safety Code (NESC) Ground rules and guidelines set by the National Electrical Safety Code for
requirements practical safeguarding of utility workers and the public during the
installation, operation, and maintenance of electric supply, communication
lines and associated equipment.
National Information Solutions An integrated mapping software solution from NISC
Cooperative (NISC) MapWise
software
National Weather Service (NWS) A U.S. federal government agency that provides weather forecasts,
hazardous weather warnings, and related products.
NOAA Weather and Hazards Data A National Weather Service tool allowing users to visualize real-time and
Viewer historical weather warnings, severe weather, hydrology, fire, and coastal
hazards from the National Oceanic and Atmospheric Administration on
interactive maps, helping emergency managers, researchers, and the
public understand and track dangerous events like floods, fires, and
hurricanes. It offers various data layers and formats, making complex
environmental data accessible.
Non-expulsion Fuse A fuse that doesn't emit molten metal when it blows, reducing fire risk.
Non-reclose Setting Disabling automatic re-energization to reduce fire risk.
Oregon Administrative Rules (OAR) State-specific regulations
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Overhead (OH) Lines Power lines above ground.
Overhead (OH) Transmission Power lines above ground that are over 25 kV
Phase Spacing The critical distance between energized conductors (phases) or between
conductors and ground, determined by voltage to prevent dangerous
electrical arcing, ensure worker safety (minimum approach distances), and
meet codes like the NESC, varying from inches for low voltage to many
meters for ultra-high voltage transmission lines, ensuring adequate
insulation.
Public Safety Power Shutoff (PSPS) Intentional power outage during extreme fire risk.
Recloser A device that automatically restores power after a fault.
Red Flag Warning (RFW) A forecast alert from the National Weather Service indicating critical fire
weather conditions, such as high temperatures, very low humidity, and
strong wind, that create an extreme risk for rapid wildfire growth or
ignition.
Relays A crucial grid component, acting as the "nervous system" to monitor
voltage, current, and frequency for faults (like overloads, short circuits,
ground faults). It rapidly trips circuit breakers to isolate problems,
preventing damage, ensuring safety, and maintaining system stability.
Right-of-Way (ROW) Land cleared around power lines for safety and access.
Riparian Relating to or situated on the banks of a river.
Rural Utilities Service (RUS) Federal agency providing guidelines for rural electric utilities.
Rural Utilities Service (RUS) Financial A mandatory filing for entities receiving USDA Rural Utilities Service loans
and Operating Report or grants, detailing their financial health, operations (like electric, water,
telecom), and performance, used by the RUS to monitor loan compliance,
assess financial viability, and ensure proper use of federal funds for rural
infrastructure. These reports cover income, expenses, assets, and
operations (e.g., miles energized, power purchased) and are required
quarterly or annually, depending on the specific funding agreement and
program.
Satellite Imaging Program Using satellite imagery and AI for vegetation management.
SCADA System Supervisory Control and Data Acquisition system for remote monitoring
and control of grid equipment.
Smart, digital devices that protect, control, and automate electric power
systems by detecting faults, abnormal conditions, and initiating fast,
Schweitzer Engineering Laboratories reliable actions like tripping breakers, ensuring safety, stability, and
(SEL) Electronic Relays efficient operation.
Secondary Distribution Feeders Low-voltage electrical lines that carry power from distribution transformers
directly to homes and businesses.
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Situational Assessment A process of evaluating an individual, project, or situation in its real-world
context to understand needs, strengths, challenges, and preferences by
observing actual performance and conditions.
Spatial Analysis for Conservation and A leading research group based at the University of Wisconsin-Madison
Sustainability (SILVIS) Lab that uses GIS, remote sensing, and spatial modeling to study human
impacts on landscapes, focusing on land use change, biodiversity, and
climate change to inform conservation policy and management for a
sustainable future.
Substation A key facility on the electric power grid that controls, converts, and
transmits electricity, acting as a vital link between power generation and
consumers by stepping voltage down from long-distance transmission
lines to local distribution lines as well as voltage regulation and protective
relays.
System Hardening Efforts Efforts to make the grid resilient to physical threats (wildfires, storms) and
cyberattacks through infrastructure upgrades like undergrounding lines,
replacing wood poles with stronger materials, using covered wires,
vegetation management, automation, and smart grid tech, plus
cybersecurity measures like strong passwords, patching, and limiting
access to protect against failures and ensure reliability during extreme
weather and other events.
Tailboard Meeting A brief, informal, on-site safety briefing before starting work to discuss
job-specific hazards, procedures, tools, and protective measures to ensure
everyone understands the risks and how to work safely.
Title 36 CFR 261.50(a) Federal regulation allowing forest supervisors to close or restrict the use of
National Forest System roads, trails or land during fire season.
Transformers / Power Transformers Crucial electrical devices that transfer energy between circuits by changing
voltage levels via electromagnetic induction.
Transmission & Distribution (T&D) The vast electrical network that moves power from generators to end
System consumers, with transmission handling long-distance, high-voltage
transport via large towers and lines (the grid's "highway"), and distribution
managing shorter-distance, lower-voltage delivery to neighborhoods,
businesses, and homes using local poles, underground cables, and
transformers to step down voltage for safe use.
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Transmission Lines High-voltage lines that carry electricity long distances. Usually 34.5 kV or
or higher.
Underground (UG) Distribution Burying electrical power lines and equipment (cables, transformers,
switchgear) beneath the ground, instead of on poles, for reliability,
aesthetics, and resilience against weather.
Underground (UG) Lines Power lines buried underground.
Vegetation Management Program A strategic plan to control or remove unwanted plants, trees, and brush
from power line rights-of-way to enhance safety, reliability from power
line rights-of-way to prevent outages and wildfires.
Voltage Regulators A piece of equipment that maintains a stable, constant output voltage,
regardless of changes in input voltage or load conditions. Its main function
is to protect sensitive components by ensuring they receive the correct,
steady voltage from a power supply.
Weather Stations Devices monitoring real-time weather conditions like temperature,
humidity, barometric pressure, wind speed, wind direction and rainfall.
Wildfire Hazard Potential (WHP) A U.S. Forest Service index and map showing the relative likelihood of
difficult-to-manage, high-intensity wildfires, using fuel, topography, and
past fire data for long-term strategic planning, not short-term forecasts.
Wildfire Mitigation Plan (WMP) A formal plan utilities create to reduce wildfire risks and comply with state
regulations.
Wildfire Standard of Care Act (WSCA) Idaho law that develops a process for electric utilities to submit Wildfire
Mitigation Plans to the Idaho Public Utilities Commission. Electric
companies would not be held liable for wildfire-related damages if they
have followed their individual wildfire mitigation plans, as approved by the
IPUC.
Wildland Fire Assessment System A US Forest Service system used to evaluate the potential for wildfires
(WFAS) based on environmental conditions.
Wildland Urban Interface (WUI) Zone where human development meets or mixes with natural,
undeveloped wildlands.
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Appendix C: Acronym Guide
Acronymn Full Words
AI Artificial Intelligence
ERP Emergency Restoration Plan
ESRI mapping software
Foliar Spraying Applying herbicide to leaves for vegetation control.
Fslim Fire Simulator
G&W Viper G&W Electric Viper
GIS Geographic Information System
HPAs Hazard Potential Areas
NESC National Electric Safety Code
NISC National Information Solutions Cooperative
NOAA National Oceanic and Atmospheric Administration
NWS National Weather Service
OAR Oregon Administrative Rules
OH Overhead
PSPS Public Safety Power Shutoff
RFW Red Flag Warning
ROW Right-of-Way
RUS Rural Utilities Service
SCADA Supervisory Control and Data Acquisition
SEL Schweitzer Engineering Labratories
SILVIS Spatial Analysis for Conservation and Sustainability
T&D Transmission & Distribution
UG Underground
USFS United States Forest Service
WFAS Wildland Fire Assessment System
WHP Wildfire Hazard Potential
WMP Wildfire Mitigation Plan
WSCA Wildfire Standard of Care Act
WUI Wildland Urban Interface
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