20260602Exhibit 1.pdf

I Peter J. Richardson ISB # 3195 RECEIVED
515 N. 271h Street JUNE 2, 2026
2 Boise, Idaho 83702 IDAHO PUBLIC
3 [phone] DD UTILITIES COMMISSION
[phone] Cell
4 peters,richardsonadams.,:o;r
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
10 IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 1
I 1 Chapter 4 "Wildfire Prevention Strategy and
Programs from" from CPC's 2022 WMP
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28 EXHIBIT NO. ICHAPTER 4"WILDFIRE PREVENTION STRATEGY AND PROGRAMS FROM" FROM
CPC'S 2022 WMP- 1

4 Wildfire Prevention Strategy anud Proarams,
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
• Vegetation Management
• Line Inspections
Fuel Source
• Right-of-Way Maintenance
• Enhanced Inspection Intervals in High-Risk Areas
• National Weather Service Monitoring
Extreme Weather • Undergrounding of Distribution Lines
• Reduced Span Length in High-Wind Areas
• Wildlife Guards
• Increased Vegetation Clearances
• Avian Protection Framing Standards
• Insulated Equipment and Jumpers
• Routine Maintenance
• Focused Design and Construction Standards
• T&D Line Inspections
9 � Failure • 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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1 T&D C.,,�erationa P, a-,-!;-es
Q ' A Sltuatinna;i Avvareress an,' i1ssess nen!_
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 GM/CEO and Chief Operating Officer (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. (nttQs-i/www.wfas.netj)
The National Weather Service (NWS): The NWS provides on line predictive fire
weather forecasting tools in the form of a current fire-weather outlook, 2-day, and a 3-8
day outlook. jhttps://wwvv spc noaa qcv/products/fire wx/)
NOAA Weather and Hazards Data Viewer: This on line 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:i, uww wrh.noaa,ciov'm .a ?wfo=psr)
Idaho Wildfire Information: Fire season requirements become effective when fire
season is declared in each Idaho Fire Restriction Area.
(http://www idahofireinfo com/p/central-idaho-fire-r?strictions.html
• 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 ofice'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.
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I i _` - rn PrecauJ-ion 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
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 GM/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.
l.� >>__ onarr Per!od
Historically, the North-Central Idaho fire season occurs between June and mid-September, with
mid-August most vulnerable to extreme fire conditions. For this WMP, the Fire Precautionary
Period (FPP) is June 151 to October 151 of each year.
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.
10 https://www.oregon.gov/odf/fire/documents/industrial-fire-precaution-levels.pdf
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4,1 4 Recioser 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. Options for resetting reclosers remotely are being
investigated by CPC.
4.1.5 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
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 GM/CEO or the
COO if the GM/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
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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.
4 �f"a}?f'V fnr f2?-PnPr;!17aY�r i
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.
nr,a�trtjcture l 'speck cros and Ma nl-pnan!-
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. The Director of Engineering
oversees the wood pole inspection program. CPC currently patrols its system at regular
intervals. Table 7 summarizes the inspection schedule for all assets, while the following plan
sections outlines 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.
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Table 7. Inspection Cycles
CLMSIFICATION
ASSIET
Line Patrol Every 2 years
overhead Transmission Detailed Inspection Every 15 years*
Pole Test and Treatment Every 15 years
Line Patrol Every 2 years
i overhead Distribution Detailed Inspection Once every 15 years*
Pole Test and Treatment Every 15 years
Line Patrol Once every 2 years
Underground Distribution
Detailed Inspection Every 15 years*
Routine Inspection Monthly
Substations
* Every 10 years for lines located in Oregon
4.2 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.
-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:
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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.
4.2.' 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.
t !a-i D Ul vi _4 ✓e Sre� - '_ ? J ;-
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
4,Z5 wood Pole Test and Treatment
The pole inspection work is performed by a third-party contractor and overseen by CPC's
Director of Engineering. "Sound"and Resistograph tests on wood poles detect decay or rot.
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.
4.2_ 6 5udstation 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
Risers and conduits
G Transformers
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Reclosers
Batteries
Capacitors
a Circuit breakers
Fire detection and suppression system (Where Applicable)
Grounding
il Voltage regulators or tap changers
Perimeter fence security
Lighting and security cameras
Irariudius !ter ItH :UYG-K epir and Rep0r+in'J
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.
—.L.� —TS Mapp;ny
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.
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 wooded
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.
4 3,1 T&D System Vegetatlon Management Overview
To minimize the interruption of electric service from power line contact and to permit
equipment access to service powerlines, 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, hot spots 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.
4 3.2 Vegetatio , 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)`., RUS, and relevant state and federal
requirements.'3. Work performed to these guidelines provides reasonable service continuity and
guards against wildfire damage caused by supply conductors.
4:3.3 Vegetation r_o 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
r
15-0 C
tlllll, i min. row,f
5
3 Phase and B Phase Primary
„W < 9h R1-30
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One or more of the following VM methods may be used at CPC's discretion depending on the
vegetation mix. Method will be determined by CPC and/or its contractor.
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 may be converted to underground at CPC's discretion.
The member or landowner will be responsible for the costs based on the applicable policy. A
credit may be included for the offset of some or all of right-of-way not cleared.
.� At-Risk vege-tahon
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.
426 ;,,'
rD ^.cq,., tS
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.
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.
4.31 8 Stol,- Damagc
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.
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4, Cieu( C!'t p!C� f-Qr-\v'\!a`; 7'p,C,J:jCatlons
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.
4 3.10 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
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.
411.4 =ire 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.
4 4,1 Wood Pole 1-iYe 'roter-tioi n
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 Figures 10.
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Figure 10. Treated Pole
i
w
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4,4.2 Avian Protection Construcbon 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.
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 Figures 11. The
elevated nesting box provides a safe place for raptors to construct their nests away from energized
equipment.
i Page � 36
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Figure 11. Avian Protection
Construction
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4 4 3 Undergrour(i 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 331 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.
4.5 Pik,e)t Rrv'.+?[ts
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.
Electronic Reciosers +kith. Remote Ad;ustabiiit r
Although CPC has 11 SEL electronic relays currently in use, CPC is evaluating adding additional
electronic relays on key feeders located in high-risk areas. This would allow remotely
configuring these relays to "non-reclose"during weather events, which may reduce the
potential for ignition. The SCADA system would need to be expanded to accomplish this goal,
however. Cellular modem and point-to-point radio are other options for communicating
remotely with this type of recloser control.
5.2 ikon-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.
4.�.3 Drone Inspection Program
Due to the challenging terrain that makes up the service area, CPC in the future may utilize
drone technology to enhance its asset inspection and VM programs. The drone would be
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. Drones may also be fitted with infrared
imaging technology, which is used to identify problem areas with spans and equipment.
`:LEARWA EP, POWER COMPAN Page 1 38
2022 Wildfire Mitigation Plan

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
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
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.
CLcP=.ti YIA T`R PCIIAJER COEMPIP ,Ni' Page 139
2022 Wildfire Mitigation Plan

I Peter J. Richardson ISB # 3195
515 N. 271h Street
2 Boise, Idaho 83702
3 [phone] DD
[phone] Cell
4 peter.ctjicliardsonadams.com
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
to IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 2
11 CPC Response to PotlatchDeltic DR#21
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EXHIBIT NO.2CPC RESPONSE TO POTLATCHDELTIC DR#21 - 1

REQUEST FOR PRODUCTION/INTERROGATORY NO. 21:
At page 23 of its 2026 WMP, CPC states (in the future tense)that it "will evaluate installing its own
weather stations at designated substations throughout the service area. " However, at page 39 of its
2022 WMP CPC states (in the present tense)that it "is investigating the options for the installation of
weather stations in substations located in high-risk areas."(Underscoring provided.] Identical
language (i.e., "is investigating') appears in CPC's 2025 WMP. Table 5 at page 15 of the 2026 WMP
provides that CPC has only one substation in a high Wildfire Hazard Potential area. Has CPC begun
or has it concluded its investigation as to the desirability of installing a weather station in its one
substation in high-fire risk area? If so, please provide copies of the results of the investigation. Has
CPC installed any weather stations in its service area? If so, please identify the locations and dates of
said installations and identify if the installed weather stations are in high risk, moderate or low risk
areas.
RESPONSE: CPC has not installed weather stations within its service area. As reflected in prior
WMPs, CPC evaluated the potential installation of weather stations at substations, including in areas
of elevated wildfire risk. This evaluation was initially prompted by recommendations from BKI
Engineering during preparation of CPC's earlier WMP.
Based on that evaluation CPC determined that installation of dedicated weather stations at
substations is not presently warranted. CPC's assessment considered the availability, quality, and
resolution of meteorological data already obtained from established and reliable third-party weather
services, as well as the operational characteristics of CPC's system. CPC concluded that existing data
sources provide sufficient situational awareness for wildfire risk monitoring and operational
decision-making, and that additional substation-level weather stations are unlikely to materially
enhance CPC's ability to take actionable measures at this time.
The differing phrasing in CPC's WMPs reflects the progression from initial investigation to
evaluation and planning. The statement in the 2026 WMP that CPC "will evaluate" installation of
weather stations reflects CPC's ongoing practice of periodically reassessing potential mitigation
measures as technologies evolve and system conditions change. It does not indicate that CPC has
deferred or failed to act on a prior commitment.
CPC's system includes only one substation identified as being in a high Wildfire Hazard Potential
area. CPC specifically considered whether installing a weather station at that location would provide
incremental operational benefit and determined that, given existing data sources and system
configuration, it would not at this time.
CLEARWATER POWER COMPANY'S RESPONSE TO REQUEST NO. 21 OF THE FIRST
PRODUCTION REQUEST AND INTERROGATORIES OF POTLATCHDELTIC FOREST
HOLDINGS, LLC
[Emphasis provided.]

I Peter J. Richardson ISB # 3195
515 N. 271h Street
2 Boise, Idaho 83702
3 [phone] DD
[phone] Cell
4 peter,cirichardsonadams.com
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
1 o IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 3
11 CPC Response to PotlatchDeltic DR#19
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EXHIBIT NO. 3CPC RESPONSE TO POTLATCHDELTIC DR#19- 1

REQUEST FOR PRODUCTION/INTERROGATORY NO. 19:
CPC's WMP provides at page 38 that 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. Please identify,
document and explain the results of all such pilot programs initiated by CPC over the past four years. Please
also identify and document all pilot programs that CPC currently "plans to initiate" in the 2026 WMP year.
Please provide copies of all "plans to initiate" pilot projects.
RESPONSE: CPC has not maintained formal written plans or reports for these pilot programs in the form
requested. The following are pilot programs referenced in the WMP:
1. Electronic Reclosers with Remote Adjustability: The 2026 target is installation of 13 single-phase and 10
three-phase reclosers. This schedule may get pushed out due to very long lead times CPC is currently
experiencing in sourcing the reclosers.
2. Non-Expulsion Fuses was identified as a possible pilot program, but has not been implemented. It is
estimated that the pilot program would take at least a year.
3. Drone Inspection Program has been moved from pilot to a standard practice.
4. Satellite Imaging Program is in the 3rd year of a 3-year pilot program.
5 Weather Stations were suggested sted by BKI Engineering when it authored CPC's initial wildfire mitigation
plan but have not been implemented because it is unclear how information from individual weather stations
would yield actionable information bond what is already obtained from the trusted weather sources already
used.
f emphasis provided]

I Peter J. Richardson ISB # 3195
515 N. 271h Street
2 Boise, Idaho 83702
3 [phone] DD
[phone] Cell
4 peter.et richardsonadams.com
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
to IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 4" Case Study Clearwater Power
I I Company --Lewiston, Idaho: Rural Idaho
Electric Cooperative Saves Restoration Time
12 With SEL Recloser Controls and Remote
Communications" © 2009 by Schweitzer
13 Engineering Laboratories, Inc.
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27 EXHIBIT NO.4"CASE STUDY CLEARWATER POWER COMPANY--LEWISTON, IDAHO: RURAL
IDAHO ELECTRIC COOPERATIVE SAVES RESTORATION TIME WITH SEL RECLOSER CONTROLS
28 AND REMOTE COMMUNICATIONS"©2009 BY SCHWEITZER ENGINEERING LABORATORIES,INC. -
1

CASE STUDY
Clearwater Power Company—Lewiston, Idaho
Rural Idaho Electric Cooperative Saves Restoration Time
With SEL Recloser Controls and Remote Communications
In a 2008 annual meeting video for Clear- Today, the company that started with a
water Power Company (CPC), longtime group of farmers who wanted to bring elec-
customers like Gene Esser of Genesee, tricity to their rural neighbors and friends in
Idaho, reminisce about when electric power, northern Idaho during the Great Depression
through the cooperative, first came to their supplies power to more than 7,750 members.
part of rural Idaho in 1937. He recalls the CPC operates 12 substations and maintains
excitement of watching the CPC line coming 2,800 miles of power lines over some of the
closer to his home. most rugged terrain imaginable.
"Before electricity came, we lived in the Many rural electric associations like CPC
kitchen, because we didn't have a hook for have the unique challenge of providing reli-
the lamp in other rooms,"he said. "After we able power to their consumers with aging
got electricity, of course, that opened up the equipment and small staffs. They require
whole house." protective relays that keep the power flow-
ing and simplify their work, and for CPC,
Dolores Corey of Avon, Idaho, has the the choice is SEL.
refrigerator—still working—that her mother
bought in 1937 for the occasion of CPC Doug Pfaff, CPC manager of engineering
connecting the electricity. for ten years, has overseen the cooperative's
move toward replacing its old equipment
"We got ice cream every day,"she said with with SEL relays and controls, specifically
a laugh. "We couldn't wait for that electric- the SEL-351R Recloser Control and
ity, oh boy, snap that light on,wonderful!" SEL-651R Advanced Recloser Control and
remote communications devices.
r SEL recloser controls are applied with ex-
isting three-phase G&W Viper-STO reclos-
ers in four substations. CPC has about 300
oil-circuit reclosers on its system and will
replace many of those over the next few
years with 20 three-phase G&W reclosers
and SEL recloser controls.
+i ► CPC was an early adopter of the SEL-351R.
1 Tube The cooperative installed a prototype unit in
66AN 10 1998 for evaluation and was so satisfied
with its performance that it was left in ser-
Figure 1—Dolores Corey of Avon, Idaho, reminisces about vice for several years, according to Pfaff.
when Clearwater Power Company first connected electricity CPC continues to use the product for fault
to herfamily's home in 1937.
Case Study—Clearwater Power Company Page 1

location, data collection, and as a remote traverse thickly wooded areas, solid rock,
terminal unit. He especially values the EZ and steep canyon walls; in some places,
recloser control settings, a list of about 40 CPC has built new lines in country so
important settings that can be custom-set for remote, a helicopter is sometimes needed to
rapid installation through ACSELERATOR place power poles. On average, one mile of
QuickSeto SEL-5030 Software. These in- line serves about 3.6 customers.
clude the following:
• Control identifier
• Current transformer(CT)and
potential transformer(PT)ratios
• Minimum trip pickup
• Curve type
• Reclose interval
• And more
Figure 3—Some of the terrain in CPC's service territory is
so remote,a helicopter is used to place power poles when the
cooperative builds new lines.
Figure 2—The SEL-351R Recloser Control. Fault currents are not high in CPC substa-
tions, Pfaff says, but they do experience
Pfaff customizes the settings because he difficulties with voltage drop. Pfaff says
wants instantaneous protection, he says, and linemen get very accurate fault locating with
that ability to customize protection sets the SEL relays. In one case, anSEL-351R pin-
SEL recloser controls apart. Rural electric pointed a fault during a heavy winter to
associations like CPC are often "one-man" within one-fifth of a mile of its actual loca-
operations with that person doing everything tion, ten miles past rural Potlatch, Idaho, in
from specifying equipment to setting it, so remote country accessible only by foot. Line
simpler is better. crews snowshoed into the area and easily
"You couldn't [customize] with a Cooper located the fault.
[control]," he says. "I think the EZ settings "The main reason we went with [the SEL
are a really good system." relay] was because we knew it would save
Fault locating on the CPC power system is us a tremendous amount of time," Pfaff
something of a challenge, given the geogra- says. "The guys were able to walk right to
phy and distances covered. Power lines the fault."
Page 2 Case Study—Clearwater Power Company

Another benefit of the SEL equipment for
CPC is in tracking harmonic distortion
events on the system. A lumber mill the
cooperative serves switched to variable-
frequency drives, which has created har-
monics problems with residential consum-
ers. CPC charges for power factor, so the
mill installed capacitors on the line as a
solution. But this only caused more
distortions. With the cooperative tracking
sag, swell, and interrupt data and harmonic
metering through the SEL-651R event
reporting capabilities, CPC could show its
customers that the problems did not origi-
nate at the substation.
Figure 4—The SEL-351R Recloser Control's fault-finding
capability is so accurate that the control pinpointed a fault
on a CPC line to within one fifth of a mile o its actual loca-
tion in heavy winter conditions.
In another case, CPC received complaints of
two blinks one evening at about 6:15 p.m.
Pfaff, on call that night, established an inter-
active Telnet connection with the SEL-351R
and found the fault location about six miles
out of the substation above Lewiston, Idaho.
He sent two linemen to investigate the
blinks in snowy weather. Directed by Pfaff,
the linemen drove to the last section of nav-
igable road, then took a four-wheeler in
another two miles and drove right to the
fault. The linemen discovered the crossarm
tilted over (because a bolt had fallen out)
and the conductor touching the pole. When
it became wet enough, it would fault.
CPC decided to set up an outage and con- Figure 5—CPC linemen work on a pole overlooking a steep
tacted the local TV channel, whose broad- rock face.Highly reliable SEL equipment saves the coopera-
tive hours of outage time by finding_laults• ac•c•uralely and
communicating exact location information back to the con-
scheduled the outage for 11:00 p.m., after trol center.
prime-time TV, but it did not wait. The fault
finally opened up the line at 10:15 p.m., and CPC also uses SEL Ethernet transceivers
connected to the serial ports on relays and
with the linemen right on the scene, they
restored power by about 11:30 p.m. recloser controls to simplify its communica-
tions and to help with remote closing and
"If we had waited until the fault finally opening of its substations. SEL Ethernet
opened up the line, as we would have before transceivers enable economical communica-
communication and fault locating, [the out- tion remotely, rather than going through
age] would have lasted most of the night," costly leased or dial-up lines. In the case of
Pfaff says. "We easily saved six hours of CPC, the information from the equipment is
outage time." brought back over its radio and satellite
Case Study—Clearwater Power Company Page 3

system to the main control center. From keep the power running to rural power users
there, data can be collected, viewed for stat- and a few larger consumers, including
us, and sent on for control commands, all lumber mills, a garnet mine near Fernwood,
from one terminal in the office. Idaho, and the Clearwater River Casino and
Resort just east of Lewiston. The coopera-
"We've done some pretty neat things with tive has grown about 1 to 2 percent a year
that on a pretty low budget,"Pfaff says. and, remarkably, utilizes much of the same
equipment it installed in the 1960s.
"It's old equipment, but we maintain it as
best we can and target what we can for re-
placement,"Pfaff says.
About CPC
Established in 1937, CPC is an electric co-
operative that serves more than 7,750 mem-
Figure 6—The SEL-2890 Ethernet Transceiver. bers in 11 counties In 3 states (Idaho,
Washington, and Oregon). The mission of
When asked about the time savings with CPC is to provide its member-consumers
remote closing, Pfaff estimates a 25 to 50 with safe, reliable, cost-based energy, and
percent improvement—half an hour for a related services. For more information, visit
straightforward outage and several hours for www.clearwaterpower.com, or contact CPC
more complicated outages. A typical two- by phone: [phone] (toll free); fax:
hour outage could easily stretch to four +1.208.746.3902; or mail: P.O. Box 997,
hours without the remote communications. 4230 Hatwai Road, Lewiston, ID 83501,
USA.
"The line crew doesn't go to the substation;
they go directly to the place they think the About SEL
problem exists," he says. "You're saving
time all the way around." SEL has been making electric power safer,
more reliable, and more economical since
Saving time for a small electric cooperative 1984. This ISO 9001:2000-certified com-
with a large service area is paramount. Of pany serves the electric power industry
the 2,800 miles of power lines CPC main- worldwide through the design, manufacture,
tains, only 200 miles are for transmission at supply, and support of products and services
69 kV. Owned by its members and governed for power system protection, control, and
by a nine-member board, CPC employs monitoring. For more information, visit
about 50 people working out of three Idaho www.selinc.com, or contact SEL by phone:
district offices: Lewiston, Princeton, and +1.509.332.1890; fax: [phone]; or
Orofino. For each district except Lewiston, mail: 2350 NE Hopkins Court, Pullman,
which has eight linemen, four-man crews WA 99163,USA.
©2009by Schweitzer Engineering Laboratories,Inc. SCHWEITZER ENGINEERING LABORATORIES, INC.
All rights reserved. 2350 NE Hopkins Court•Pullman,WA 99163-5603 USA
All brand or product names appearing in this document are Tel:[phone]•Fax:[phone]
the trademark or registered trademark of their respective www.selinc.corn•www.selindustrial.com
holders.No SEL trademarks may be used without written Email:[e-mail]
permission. Illllll�lll�lllllllbllllbllll�lll�llllllll
SEL products appearing in this document may be covered by
US and Foreign patents.Date Code 20090424
Page 4 Case Study—Clearwater Power Company

I Peter J. Richardson ISB # 3195
515 N. 27`h Street
2 Boise, Idaho 83702
3 [phone] DD
[phone] Cell
4 petergrichardsonadams.com
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
10 IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 5
11
RUS BULLETIN 1730B-121
12
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EXHIBIT NO. 5RUS BULLETIN 1730B-121 - 1

Disclaimer: The contents of this guidance document does not have the force and effect of law and is not
meant to bind the public in any way. This document is intended only to provide clarity to the public
regarding existing requirements under the law or agency policies.
UNITED STATES DEPARTMENT OF AGRICULTURE
Rural Utilities Service
RUS BULLETIN 1730B-121
RD-GD-2013-71
SUBJECT: Wood Pole Inspection and Maintenance
TO: All Electric Borrowers
EFFECTIVE DATE: Date of Approval.
OFFICE OF PRIMARY INTEREST: Transmission Branch, Electric Staff Division.
FILING INSTRUCTIONS: This bulletin replaces RUS Bulletin 1730B-121, "Pole Inspection
and Maintenance," issued April 15, 1996.
PURPOSE: To furnish information and guidance in establishing a continuing program of pole
maintenance.
August 13, 2013
NiNi I Date
Assistant Administrator
Electric Program

RUS Bulletin 1730B-121
Page 2
TABLE OF CONTENTS
Page
1 PURPOSE................................................................................................................................3
2 GENERAL DISCUSSION OF POLE DECAY ......................................................................3
3 PLANNED INSPECTION AND MAINTENANCE PROGRAM..........................................6
4 INSPECTION METHODS.............................................................................................•........8
5 ADDITIONAL INSPECTION TOOLS AND METHODS ....................................................9
6 RESULTS OF WOOD POLE INSPECTION.......................................................................10
7 REMEDIAL TREATMENT..................................................................................................11
8 DETERMINING THE SERVICEABILITY OF DECAYED POLES..................................14
Exhibits
Exhibit A: Metric Conversion Factors
ABBREVIATIONS
ACA - Ammoniacal copper arsenate
ACZA - Ammoniacal copper zinc arsenate
ANSI - American National Standards Institute
AWPA - American Wood Protection Association
CCA - Chromated copper arsenate
EPA - Environmental Protection Agency
NaMDC - N-methyldithiocarbamate
NESC - National Electrical Safety Code
MITC - Methylisothiocyanate
pcf - pounds per cubic foot
RUS - Rural Utilities Service

RUS Bulletin 1730B-121
Page 3
1 PURPOSE
To furnish information and guidance to electric cooperatives in establishing a continuing
program of pole maintenance and to operating personnel in performing inspection and
maintenance of standing poles. Included in this bulletin are methods and procedures for
determining the minimum permissible groundline circumferences of distribution and
transmission poles.
2 GENERAL DISCUSSION OF POLE DECAY
Pole Decay. Decay of treated poles is usually a gradual deterioration caused by fungi and
other low forms of plant life. Damage by insect attack(termites, ants and wood borers) is
usually considered jointly with decay because preservative treatment of wood protects
against both fungi and insects. In most cases, the decay of creosote and penta-treated
poles will be just below the groundline where the conditions of moisture, temperature and
air are most favorable for growth of the fungi. Factors affecting pole life, such as species
of wood, type and thoroughness of treatment, geographical location, and soil conditions
are discussed below.
a Pole Species. Of the millions of poles on RUS financed systems, about 85
percent are the thick sapwood southern pines. Untreated, the sapwood is
especially vulnerable to attack by wood destroying fungi, termites, and carpenter
ants. In the Gulf States, where temperature and moisture are most favorable for
growth of these major wood-destroying organisms, the time to pole failure of an
untreated pole would be 2 to 3 years. In areas of lower rainfall and few frost-free
days, the time to pole failure would increase to 5 to 10 years.
The bulk of the remaining pole population is classified as the western species,
comprised of Douglas-fir, western red cedar, red pine, lodgepole pine, ponderosa
pine and a small amount of jack pine.
Adequate preservative treatment protects the pole sapwood and the underlying
heartwood. Heartwood of these pole species varies not only in decay resistance,
but is difficult to treat with preservatives. The heartwood decay resistance for the
major pole species is as follows:
Durable-Western red cedar heartwood.
Moderately Durable-Douglas-fir and most of the pines.
Least Durable- Lodgepole pine. (The use of this species has been limited
primarily to the Mountain States areas.)
b Preservative Treatments. There are two general classes of preservative treatment,
oilborne (creosote,penta in petroleum, and Copper Naphthenate) and waterborne
(arsenates of copper). Creosote was the only preservative for poles on rural

RUS Bulletin 1730B-121
Page 4
systems until 1947, when post-war shortages prompted the introduction of
pentachlorophenol (penta) and Copper Naphthenate. Both of these preservatives
were dissolved in fuel oils from petroleum or mixtures with creosote.
For many years,penta has been the most widely used preservative for poles. With
the increase in cost of petroleum-based products,penta-in-oil treated pole costs
have also increased. Presently,both penta and waterborne preservatives are
widely used with both preservatives having performed satisfactorily. Where
problems have occurred with penta treated poles, the decay can be tied to poor
conditioning of the poles, to the loss of solvent carrier due to migration and
bleeding or to loss of dissolved penta to retentions below the effective
preservative threshold. To overcome these losses, treatments and quality control
have been improved.
Standard wood preservatives used in waterborne solutions include ammoniacal
copper zinc arsenate (ACZA), and chromated copper arsenate (CCA) (types A, B,
and Q. These preservatives are often employed when cleanliness and paintability
of the treated wood are required. Several formulations involving combinations of
copper, chromium, and arsenic have shown high resistance to leaching and very
good performance in service. Both ACZA and CCA are included in many
product specifications for materials such as building foundations,building poles,
utility poles, marine piles, and piles for land and fresh water use. Treatment
usually takes place at ambient temperature. Care needs to be taken during
treatment to ensure heat sterilization of the pole when treating Douglas-fir with
ACZA.
c Decay Zones. The following Decay Severity Zones on a map of the United States
was originally based on summer humidity and temperature information and later
on a pole performance study conducted by RUS. Decay severity ranges from
least severe in Zone 1 to most severe in Zone 5. Service life records and
individual experience or a planned sample inspection will indicate if the decay
hazard for a system is typical of the zone in which the system is located.

RUS Bulletin 1730B-121
Page 5
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Decay severity zones for wood utility poles as defined by the USDA Rural Utilities
Service. Decay is least severe in zone 1, most severe in zone 5.
d Types of Decay. Internal decay may be found in southern pine poles that were
not properly conditioned or in which penetration or the amount(retention) of
preservative is inadequate. Internal decay of the western species usually involves
the heartwood in butt-treated western red cedar, lodgepole pine, and Douglas-fir
which have been improperly seasoned prior to treatment. After installation, decay
organisms invade the heartwood through the poorly treated sapwood zone checks,
or woodpecker holes. Internal decay may also occur in field framed poles when
supplementary treatment is neglected.
Insufficient treatment or migration of oil-type preservatives is the principal cause
of external decay in southern pine poles. This decay is generally the result of
improper seasoning or treatment. Inspection methods should be directed toward
discovery of this type of defect and maintenance efforts to supplement the
treatment with additional chemicals.
External decay above ground, or better known as "shellrot", may occur in butt-
treated western red cedars after 12-15 years of service.

RUS Bulletin 1730B-121
Page 6
3 PLANNED INSPECTION AND MAINTENANCE PROGRAM
Purpose. The purpose of a planned inspection program is to reveal danger poles and
poles which are in early stages of decay so that corrective action can be taken to prolong
the service life of the pole. The end result of the inspection program is the establishment
of a continuing maintenance program for extending the average service life of all poles
on the system. The steps in developing a planned pole inspection and maintenance
program are outlined below.
a Spot Checking. Spot checking is the initial step in developing a planned pole
inspection and maintenance program. Spot checking is a method of sampling
representative groups of poles on a system to determine the extent of pole decay
and to establish the priority for a pole maintenance program. A general
recommendation is to inspect a 1,000 pole sample made up of continuous pole
line groupings of 50 or 100 poles in several areas of the system. The sample
should be representative of the poles in place. For instance, all the poles on a line
or a map section should be inspected as a unit and not just the poles of a certain
age group. The inspection of the sample should be complete, consisting of
hammer sounding, boring, and excavation as described in Section 4. Field data
should be collected on the sample as to age, supplier, extent of decay, etc.
After the data has been collected, it should be analyzed to determine the areas
having the most severe decay conditions and to establish priorities of a pole-by-
pole inspection of the entire system. It may be desirable to take additional
samples on other portions or areas of the system to determine if the severity of
decay is significantly different to warrant the establishment of an accelerated pole
inspection and maintenance program for that portion of the system. The results of
the spot check will aid in scheduling a continuous pole inspection and
maintenance program at a rate commensurate with the incidence of decay.
b Schedulingthe a Inspection and Maintenance Program. The results of the spot
check will aid in determining when the planned program should be started. The
suggested timing for initial pole-by-pole inspection and subsequent re-inspection,
when supplementary treatment is applied after each inspection, is as follows:
Decay Zone Initial Inspection Subsequent Percent of
Re-inspection Total Poles
Ins ected Each Year
1 12— 15 Years 12 Years 8.3
2 and 3 10— 12 Years 10 Years 10
4 and 5 8 - 10 Years 8 Years 12.5
The vulnerability of poles to decay is generally proportionate to the decay zone in
which they are located. As a general recommendation, the initial pole-by-pole
inspection program should be inaugurated at a yearly rate of 10 percent of the
poles on the entire system when the average age of the poles reaches 10 years. If

RUS Bulletin 1730B-121
Page 7
a spot check indicates that decay is advanced in 1 percent of the pole sample, the
inspection and maintenance program should be accelerated so that a higher
percentage of poles are inspected and treated sooner than the figures shown
above. If the decay rate is low for a particular decay zone or area of the system,
the pole-by-pole inspection can be postponed accordingly. Historical inspection
data indicates that the ratio between the decaying/serviceable poles to reject poles
in the 10-15 year age group is about six or more to one. In a 30-year age group, it
is about one to one or less. In the latter group, the survivors have more than
sufficient residual preservative to protect them indefinitely. The poorly treated
poles in the 30-year old group have already decayed and been replaced.
The greatest economic benefit from regular inspection is in locating the
decaying/serviceable group. Treatment of poles in this group can extend pole life,
thereby saving the cost of emergency replacement. Inspection and proper
maintenance can more than pay dividends by extending the serviceable life of the
poles. With the costs of replacing poles rising, the economics of extending the
service life are more favorable.
c Establishing the Program. The pole-by-pole inspection and maintenance work
may be done by system employees or by contracting with an organization
specializing in this type of work. The choice should be made on the basis of the
amount of work to be done, the trained employees available, and a comparison of
the costs. Developing the necessary skills in the system's own crews may require
considerable time and be contingent upon the availability of an experienced
inspector to train system employees. Therefore, qualified contract crews may be
preferable for this work in many instances. An inspector to be qualified should
have inspected, as a minimum, 5,000 poles in conjunction with a qualified
inspector and another 5,000 on his own, but under close supervision. The
inspector's work should be checked every week or two by the system's
representative and the inspector's supervisor. To check an inspector's work
select at random about 10 poles, inspected in the previous few weeks, re-excavate,
take off paper and treatment, and re-inspect. Check for hollow sounds, take a
boring, check soft surface wood, especially adjacent to shaved areas or along
checks, re-measure the pole, recheck the calculations, then retreat and backfill. If
any serious errors are discovered, all the work between these spot checks should
be re-inspected.
The pole inspection and maintenance program may result in a large number of
replacements. If the reject rate is high, the system's crews may not be able to
replace rejected poles in a reasonable time because of other work. The temporary
addition of skilled personnel for inspection or pole replacement may be required.
It is generally necessary to use at least one crew full time to keep up with the pole
inspector. An average pole inspector can check 150-200 poles per week or 800
poles per month. It is desirable to have one person responsible for supervision
and coordination.

RUS Bulletin 1730B-121
Page 8
d Re-inspections. Information obtained during the first pole-by-pole inspection can
serve as the basis for scheduling subsequent inspections. As a guide, it is
recommended that a re-inspection be made every 8 to 12 years as shown in
paragraph 3c of this Section, according to the decay zone and severity of decay.
The recommended re-inspection intervals are based on treating poles during the
previous inspection cycle. Shorter re-inspection intervals are recommended if
poles were not treated. These recommendations may be modified by experience,
but the intervals should not be extended by more than 3 years. It is advisable to
recheck some poles which have been groundline treated. At the completion of the
inspection of a pole, a small, weatherproof tag should be attached to the pole
indicating the organization that performed the inspection and the date of the
inspection.
4 INSPECTION METHODS
Inspection Types. There are varying types of inspection, each with a different level of
accuracy and cost. Inspection methods with low accuracy require more frequent re-
inspection than methods which are detailed and more accurate.
a Visual Inspection. Visual inspection should be considered the first step to
inspecting poles but has the lowest accuracy. Since most decay is underground or
internal, this method will not detect the majority of defective poles. Obvious data
can be collected on each specific structure, such as the condition of the pole above
ground, crossarm, and hardware. This method is not recommended for detecting
decay.
b Sound and Bore. This method involves striking a pole with a hammer from
groundline to as high as the inspector can reach and detecting voids by the hollow
sound. An experienced inspector can obtain significant information about a pole
by listening to the sounds and noticing the feel of the hammer. The hammer
rebounds more from a solid pole than when hitting a section that has an internal
decay pocket. The internal pocket also causes a sound that is dull compared to the
crisp sound of a solid pole section.
Some contracts require all poles to be bored, while others require boring only
when decay is suspected. Boring is usually done with either an incremental borer
or power drill with a 3/8" bit. An experienced inspector will notice a change in
resistance against the drill when it contacts decayed wood. The shavings or the
borings can be examined to determine the condition of the wood, and the borings
can be analyzed for preservative penetration and retention.
When voids are discovered a shell thickness indicator can be used to measure
them. This information can be used to evaluate the reduction strength by the void.
The effectiveness of the sound and bore method varies by species. For southern
yellow pine poles, which represent a majority of the poles in North America,

RUS Bulletin 1730B-121
Page 9
decay normally is established first on the outside shell below ground. The decay
moves inward and then upward to sections above ground. By the time sound and
bore inspection can detect internal decay pockets above ground, the pole is likely
to have extensive deterioration below ground.
Sound and bore method is more effective with Douglas-fir and western red cedar.
Decay on these poles is likely to begin internally near the groundline, or in the
case of Douglas-fir, above the groundline. Therefore, sounding and boring can
identify at least some decay at a stage before the groundline section is severely
damaged. All borings should be plugged with a treated wood plug which is
properly sized for the respective hole.
c Excavation. The effectiveness of the sound and bore inspection is greatly
increased when excavation is added to the process. Excavation exposes the most
susceptible section of the pole for inspection. For southern yellow pine this is
particularly true, since decay begins externally and below ground.
Poles should be excavated to a depth of 18 inches in most locations. Deep
excavation may be required in dry climates. After excavation the exposed pole
surface should be scraped clean to detect early surface decay.
Shell rot and external decay pockets should be removed from the pole using a
specially designed chipper. Axes or hatchets should not be used for this
application. The remaining pole should be measured to determine if the pole has
sufficient strength with the reduced circumference. Tables 2, 3, and 4 assist in
adjusting circumferences for various size voids.
After complete inspection and application of preservative treatment,the pole is
backfilled. The dirt should be tamped firm every 6 to 8 inches. The backfill
should mound up around the pole to allow for future settling and drainage away
from the pole.
5 ADDITIONAL INSPECTION TOOLS AND METHODS
Additional Methods. Over the past several years there has been a considerable amount of
research work done by companies to develop additional products that can be incorporated
into the in-line pole inspection process. These products, involving many diverse
technologies, are intended to improve both the accuracy and reliability of the in-line
inspection programs used by utilities, as well as decrease the time necessary to carry out
the inspection process. In developing comprehensive inspection programs, cooperatives
are encouraged to examine all potential inspection tools and processes to determine the
best system for their particular needs. The data from these testing devices does not
always correlate exactly with the actual bending strength determined by full scale testing
and, as a result, should be used to establish trends showing changes in strength.

RUS Bulletin 1730B-121
Page 10
6 RESULTS OF WOOD POLE INSPECTION
a Inspection Results. Inspection results should be used to update pole plant records,
evaluate pole condition, plan future inspection and maintenance programs, and
provide information for map revisions. The inspection process will result in
identifying the condition of each individual distribution or transmission pole.
In general the National Electric Safety Code (NESC)requires that if structure
strength deteriorates to the level of the strength reduction factor required at
replacement, the structure shall be replaced or rehabilitated. The inspection
results should indicate if a pole is "serviceable" or a"reject".
b Serviceable. The characteristics of"serviceable" are based on the following
conditions:
(1) Large portion of completely sound wood.
(2) Early stages of decay which have not reduced the pole strength below
code requirements.
(3) Pole condition as stated above but a defect in equipment may exist, such
as a broken ground or loose guy wire. Equipment defects should be
subsequently repaired.
c Rejects. Any poles that do not meet the above conditions should be classified as
"rejects". Their characteristics are:
(1) Decay, insect or mechanical damage has reduced pole strength at the
groundline below code requirement.
(2) Severe woodpecker hole damage has weakened the pole below safety
standards.
(3) Hazardous conditions exist above ground, such as split top.
d Reinforce or Replace. Rejected poles may be classified further depending on the
severity of the deterioration and whether they are reinforceable.
(1) A"reinforceable reject"is any reject which is suitable for restoration of.
the groundline bending capacity with a method of reinforcement.
(2) A"replacement"candidate would be a rejected pole which is not suitable
for the necessary rehabilitation.

RUS Bulletin 1730B-121
Page 11
7 REMEDIAL TREATMENT
Purpose. The purpose of remedial treatment of standing poles is to interrupt the
degradation by the addition of chemicals, such as pesticides, insecticides and fungicides,
thereby extending the useful life of the structure. Treatment may be external groundline
treatment or internal treatment.
a Regulations and Licensing. The majority of states require that applicators or the
job supervisor obtain a pesticide applicator license. Testing for this license
includes a"basic skills test" to show knowledge of the rules and regulations
governing pesticides. Some states also give a "category test" which is specific to
wood poles and wood preservation. The uses of every pesticide are classified by
the U.S. Environmental Protection Agency(EPA) as either "general" or
"restricted".
(1) A "general use"pesticide is not likely to harm humans or the environment
when used as directed on the label. These preservatives may be purchased
and applied without a pesticide applicator license. However, a
manufacturer may choose not to make a product available for purchase by
the general public.
(2) A "restricted use"pesticide could cause human injury or environmental
damage unless it is applied by competent personnel (certified applicators)
who have shown their ability to use these pesticides safely and effectively.
These wood preservatives can only be purchased and applied by someone
who has a pesticide applicator license or whose immediate supervisor has
a pesticide applicator license.
b Groundline Treatment. All treated poles eventually lose resistance to decay.
Groundline treatment with effective preservatives provides an economical
extension of their physical life. Experience has shown that a well designed and
implemented groundline inspection and maintenance program can significantly
increase the service life of many poles. Groundline external treatment is
recommended under the following conditions:
(1) Whenever a pole is excavated during an inspection, and the pole is sound
or decay is not so far advanced that the pole must be replaced or
rehabilitated.
(2) Whenever a pole over 5 years old is set.
(3) Whenever a used pole is installed as a replacement.
External preservatives used for groundline treatment typically contain active
ingredients that are either water soluble, oil soluble or practically insoluble.

RUS Bulletin 1730B-121
Page 12
Before application of external preservatives, decayed wood should be stripped
from the pole and removed from the excavation. The preservative paste is most
commonly brushed onto the pole following label directions. A polyethylene
backed paper is then wrapped around the treatment and stapled to the pole. The
paper aids the migration of the preservative into the critical outer shell.
c Internal Treatment. The three basic types of preservatives used for internal
treatment are liquids, fumigants, and solids.
(1) Liquid Internal Preservative: Liquid internal preservatives should be
applied by pressurized injection through a series of borings that lead to
internal decay pockets or voids. Adequately saturating the pocket and
surrounding wood should arrest existing decay or insect attack and prevent
further degradation for an extended time.
Liquid internal preservatives contain water soluble or oil soluble active
ingredients. Sodium fluoride, boron and various forms of copper solutions
are the principle active ingredients used today. Moisture that is present in
the pole will help facilitate diffusion of the active ingredients into the
wood beyond a decay pocket.
Oil based internal preservatives most often incorporate Copper
Naphthenate as an active ingredient with fuel oil or mineral spirits as the
solvents. Since oil-based Copper Naphthenate is not soluble in water, it is
likely to migrate into the surrounding wood only as far as the oil will
travel.
(2) Fumigants: Most of the fumigants in use for wood poles today were
originally developed for agricultural purposes. Applying fumigants to soil
will effectively sterilize the ground. Due to high levels of microorganisms
and chemical activity in soil, the fumigants will degrade fairly rapidly and
dissipate so that new crops can be planted in a short time.
These same fumigants do not degrade rapidly in wood and will remain
affixed to sound wood cell structure for many years. Fumigants have also
been found to migrate longitudinally in wood, several feet away from the
point of application. This helps control decay in a large section of the
pole. When the vapors migrate into a decay void, however, they may
dissipate through associated checks and cracks. This reduces the long
term efficacy and requires more frequent application.
Registered pole fumigants include Sodium N-methyldithiocarbamate
(NaMDC), Methylisothiocyanate (MITC),tetrahydro-3,5-dimethyl-2H-
1,3,5-thiadiazine-2-thione (Dazomet) and Chloropicrin. Chloropicrin is a
very effective wood fumigant. However,the liquid must be applied from

RUS Bulletin 1730B-121
Page 13
pressurized cylinders, and the applicator must wear a full-face air
respirator.
MITC, NaMDC and Dazomet are the most widely used wood pole
fumigants. Pure MITC is a solid below 94°F and contains 97 percent
active ingredient. Solid MITC sublimes directly into fumigant vapors.
Avoiding the liquid stage helps to minimize loss of fumigant during
application through checks and cracks. MITC is packaged in aluminum
tubes to facilitate installation. Just before placing the tube into a treatment
hole, the cap is removed. As with any fumigant, application holes should
be plugged with pressure treated wooden or plastic plugs.
NaMDC is soluble in water to a maximum amount of 32.7 percent.
Treatment holes drilled in a wood pole are filled with the aqueous solution
so the appropriate dosage is applied. Recommended dosages vary
according to pole size. The NaMDC solution decomposes and generates
MITC as the main fungi-toxic ingredient. The maximum theoretical
amount of resultant MITC at ideal conditions is 18.5 percent by weight.
After decomposition the MITC vapors then migrate up and down the pole
to help control decay.
Dazomet is a very fine granular material that is 98-99% active ingredient.
Treatment holes drilled in a wood pole are filled with the granular material
so the appropriate dosage is applied. Like NaMDC, Dazomet decomposes
and generates MITC as the main fungi-toxic ingredient. The maximum
theoretical amount of resultant MITC at ideal conditions is 45.0 percent by
weight. The MITC vapors then migrate up and down the pole to help
control decay.
(3) Solids: Currently there are several solid diffusible rods available as a
supplemental preservative treatment for wood poles. Active ingredients
used in these rods include Sodium Fluoride, Boron and Copper. The
migration of these ingredients through the wood to control or prevent
internal fungal decay is aided by the moisture content present. The zone
of effective treatment is determined by the distance the active ingredients
move from the point of application at fungi-toxic levels. Studies have
shown wood moisture content in excess of the fiber saturation point
(approximately 30%) are necessary for significant migration to occur.
However, at wood moisture levels typically found at groundline in the
internal regions of in-service utility poles, adequate diffusion can be
achieved with an appropriate drill pattern in the treatment zone. Active
ingredients from rods will tend to move slower than fumigants.
Preservative rods should be applied according to the label directions. The
rods are typically applied through a pattern of downward angled holes
beginning at groundline or below with application rates varying with pole

RUS Bulletin 1730B-121
Page 14
circumference. Diffusible rods can also be used to sterilize inspection
holes and to control or prevent pole top decay.
d Woodpecker Damage. Woodpecker damage is an on-going issue that must be
continually addressed. Many preventative methods are available but each
typically has a varying degree of success.
It is difficult to predict which poles woodpeckers may select. Frequently the first
hole invites further attack by other woodpeckers. For these reasons, it is good
maintenance practice to seal up the smaller holes. Various materials are available
for plugging the holes, and a wire mesh can be used to cover the plugged hole as
well as large areas of a pole. In addition, as a preventative measure, wire mesh
can be applied to poles in areas where woodpecker activity is expected. Some of
these repairs restore varying degrees of strength to the pole, while others simply
plug the hole.
e Pole Reinforcement. Various methods are available to reinforce a deteriorated
pole at the ground line. A determination must be made as to whether or not a
sufficient cross section of sound wood remains at the ground line if pole
reinforcement is to be used. When considering reinforcement options, consult
with the pole reinforcement system supplier for design and installation support.
Even though reinforcement may not be economically justified, other factors may
need to be considered such as difficulty of access to the pole for replacement or
system critical load which would prevent the,line from being taken out of service
at the time when the pole may be in danger of failing.
8 DETERMINING THE SERVICEABILITY OF DECAYED POLES
Serviceability. The decision to treat or replace a decayed pole depends upon the
remaining strength or serviceability of the pole. The permissible reduced circumference
of a pole is a good measure of serviceability. The following procedure may be used to
assist in determining if a pole should be replaced or reinforced.
a Decav Classifications. Decay at the groundline should be classified as:
(1) General external decay
(2) External pocket
(3) Hollow heart, or
(4) Enclosed pocket.
b Permissible Reduced Circumference. The 2012 edition of the National Electric
Safety Code (NESC)requires that wood structures shall be replaced or
rehabilitated when deterioration reduces the structure strength to 2/3 of that
required when installed for NESC District loading. The NESC 2012 also requires
that wood structures shall be replaced or rehabilitated when deterioration reduces

RUS Bulletin 1730B-121
Page 15
the structure strength to 3/4 of that required when installed for NESC extreme
wind or extreme ice with concurrent wind loadings.
Computer programs are available that can calculate the remaining capacity of the
pole by taking the voids into account when determining the effective remaining
section of the pole.
Tables 1 through 4 will assist in determining when replacement or rehabilitation is
necessary. If the reduced circumference indicates a pole at or below the minimum
reduced circumference, the pole should be replaced, splinted, stubbed
immediately, or otherwise rehabilitated.
c General Procedure for Using Table 1,2. 3 and 4
(1) General External Decay. After removing all the decayed wood,measure
the circumference above and below the decayed section to determine the
original circumference. Then measure the reduced circumference at the
decayed section. Enter Table 1, Column 1,with the original pole
circumference. After determining the acceptable level of deterioration as
described in paragraph 8c, find the minimum acceptable reduced
circumference from the appropriate column - Column 2 for 2/3 of the
original circumference, or Column 3 for 3/4 of the original circumference
- on the same line as the original circumference. If the actual reduced
circumference is larger than the acceptable calculated minimum, from
Column 2 or 3, replacement or rehabilitation is not required yet.
(2) External Pockets. Remove decayed wood and take measurements of the
depth and width of the pocket. Measure the pole for the original
circumference. Refer to Table 2 to determine the circumference reduction.
Use the procedure from paragraph 8d(1)to determine the minimum
acceptable reduced circumference. If the actual reduced circumference,
i.e. the original circumference minus the circumference reduction from
Table 2, is larger than the acceptable calculated minimum from Table 1,
Column 2 or 3, replacement or rehabilitation is not required yet.
(3) Hollow Heart(Heart Rot). If hollow heart is found, determine the shell
thickness and measure the original circumference of the pole. Refer to
Table 3 to determine the circumference reduction. Use the procedure from
paragraph 8d(1)to determine the minimum acceptable reduced
circumference. If the actual reduced circumference, i.e. the original
circumference minus the circumference reduction from Table 3, is larger
than the acceptable calculated minimum from Column 2 or 3, replacement
or rehabilitation is not required yet.
To determine the shell thickness,bore three holes (preferably of 1/4- or
3/8-inch diameter), 120' apart; measure the shell thickness at each hole,

RUS Bulletin 1730B-121
Page 16
add the measurements, and divide by 3. Treat and plug holes with tightly
fitting cylindrical wood plugs that have been treated with preservative
once shell thickness is determined. A transmission pole with a shell
thickness less than 3 inches should be removed from service.
(4) Enclosed Pocket. An enclosed pocket is an off-center void as shown in
Table 4 and its diameter should be measured by boring holes as described
in paragraph 8d(3). Using the minimum thickness of the shell, refer to
Table 4 for the reduction in circumference. Measure the original
circumference. Use the procedure from paragraph 8d(1)to determine the
minimum acceptable reduced circumference. If the actual reduced
circumference, the original circumference minus the circumference
reduction from Table 4, is larger than the acceptable calculated minimum
from Column 2 or 3, replacement or rehabilitation is not required yet.

RUS Bulletin 1730B-121
Page 17
Table 1
Reduced circumferences for NESC Rules 250B, 250C, and 250D
Rule 250B- Rule 250C- Extreme wind
Combined ice and wind district and
loading Rule 250D- Extreme ice and
concurrent wind
Original Minimum Reduced Circumference Minimum Reduced Circumference
Circumference (in) (in)
(in) (Based on 2/3 initial strength) (Based on 3/4 of initial strength)
30 26.2 27.3
31 27.1 28.2
32 28.0 29.1
33 28.8 30.0
34 29.7 30.9
35 30.6 31.8
36 31.5 32.7
37 32.3 33.6
38 33.2 34.5
39 34.1 35.4
40 35.0 36.3
41 35.8 37.3
42 36.7 38.2
43 37.6 39.1
44 38.4 40.0
45 39.3 40.9
46 40.2 41.8
47 41.1 42.7
48 41.9 43.6
49 42.8 44.5
50 43.7 45.4
51 44.5 46.3
52 45.4 47.3
53 46.3 48.2
54 47.2 49.1
55 48.1 50.0
56 48.9 50.9
57 49.8 51.8
58 50.7 52.7
59 51.5 53.6
60 52.4 54.5

RUS Bulletin 1730B-121
Page 18
_ Table 2
DEPTH Reduction in Measured Circumferences to Compensate
WIoT0, for External Pockets
Pocket
Width (in) 1 2 3 4 5 6
Pocket
Depth Pocket
172 3 4 5 1 2 3 4 5 1 2 3 4 5 1 2 3 4 5 1F2F 4 5 1 2 3 4 5
Measured
Circumferen
ceofPole Reduction in Circumferences (in)
(in)
20 to 30 1 11 2 - - 2 2 3 - - 21 3 4 - - 13 4 5 - - 4 6 8 - - 1 6181
to 40 1 1 1 2 - 1 2 2 3 3 2 3 4 4 4 2 4 t55 6 3 5 6 7 8 5 7 8 9 -
40 to50 1 1 1 2 2 1 2 2 3 3 2 3 3 4 4 2 3 6 3 4 5 6 7 3 5 6 7 8
50to60 1 1 1 2 2 1 2 2 3 3 2 3 3 4 4 2 3 5 3 4 4 5 6 3 4 5 6 7
Table 3
Reduction in Measured Circumferences to
sa+e�i Compensate
For Hollow Heart
Measured
Minimum Thickness of Shell (ins)
Circumference
Of Pole (ins) 2 2.5 3 3.5 4 4.5
20 to 25 1 - - - - -
25 to 30 2 1 - - -
30 to 35 3 2 _ 1 - - -
35 to 40 4 3 2 1 - -
40 to 35 5 4 3 2 1 -
40 to 45 1 7 5 1 4 1 3 2 1

RUS Bulletin 1730B-121
Page 19
cc:, SHELL Table 4
Reduction in Measured Circumferences to Compensate
For Enclosed Pockets
Diameter of Pocket
(in) 3 4 5
Shell Thickness (in) 1 2 3 1 2 3 1 2 3
Measured
Circumferences Of Reduction in Circumferences (in)
Poles (in)
20 to 30 2 1 - 3 1 - 4 2 -
30 to 40 2 1 1 3 1 1 4 2
40 to 50 2 1 1 3 2 1 4 3 1

RUS Bulletin 1730-B 121
Exhibit A
Page 1
METRIC CONVERSION FACTORS
To Convert From To Multiply b
Foot ft. Meter m 0.3048
Inch(in) Centimeter cm 2.54
Degrees Fahrenheit Degrees Celsius 5/9 (X° -32)
X°F) (°C)

I Peter J. Richardson ISB # 3195
515 N. 271h Street
2 Boise, Idaho 83702
3 [phone] DD
[phone] Cell
4 peg ter,1,ricliardsonadams.coin
5
6 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
7
8 IN THE MATTER OF CLEARWATER Case No.: COI-E-26-01
9 POWER COMPANY'S APPLICATION FOR
APPROVAL OF THE COMPANY'S 2026
1 o IDAHO WILDFIRE MITIGATION PLAN Exhibit No. 6
11
Clearwater Potlatch Timber Protective
12 Association, Inc. Report of the Chief Fire
Warden, Orofino, Idaho December 31, 2025.
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28 EXHIBIT NO.6 CLEARWATER POTLATCH TIMBER PROTECTIVE ASSOCIATION, INC. REPORT OF
THE CHIEF FIRE WARDEN,OROFINO, IDAHO DECEMBER 31,2025.- 1

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Annual Report 2025

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earwaler— o a1c 3300181100, 004
l er r oleclivs
The Clearwater Timber Protective Association and the Potlatch Timber Protective Association were separately organized in
the early 1900's. In 1966, these two entities merged to form the Clearwater-Potlatch Timber Protective Association, a
non-corporate entity. Subsequently, on July 16, 1982,the Association completed filings for incorporation under the Idaho
Nonprofit Corporation Act and became the Clearwater-Potlatch Timber Protective Association, Inc. (C-PTPA).
The mission of the C-PTPA is to provide safe, aggressive, effective wildland fire suppression on almost one million acres of
Idaho's private, state, and federally owned lands.
The Association is controlled by forest landowners belonging to its membership and subject to the provisions of the Idaho
Forestry Act. The Association is primarily responsible for the conservation and protection of the forests and forestland
within the State of Idaho; specifically,the Palouse, Potlatch and North Fork of the Clearwater River drainages.
The C-PTPA maintains an administrative complex in Orofino and three satellite fire camps strategically located in our
protection area. In an effort to keep unwanted fires as small as possible,four separate facilities are maintained to reduce
arrival time on fires.
C-PTPA Official Directory
OFFICERS DIRECTORS
Sam Renner, President Sam Renner PotlatchDeltic Corporation
Greg Danly, Vice President Mike Reggear Idaho Forest Group
Kane Steinbruecker, Secretary-Treasurer Jason Svancara State of Idaho
Kane Steinbruecker, Chief Fire Warden M. John Larson M. John Larson Logging
Kimberly S-Browning, Assistant Secretary-Treasurer Greg Danly Empire Lumber Company
Mike Cook Small Landowner Representative
FIRE COMMITTEE
Directors serve as Fire Committee -
4.
AUDIT COMMITTEE ' •� '
Greg Danly, Chairman
Board of Directors serve
as Committee
LEGISLATIVE COMMITTEE
Jason Svancara, State of Idaho ;F-J '
y - �` -
�

neport of tne Chief Fire Warden
Orofino, Idaho, December 31, 2025
Officers, Members, and Directors:
CLEARWATER — POTLATCH TIMBER PROTECTIVE ASSOCIATION, INC.
I respectfully submit the annual report for the Clearwater-Potlatch Timber Protective Association, period
January 1, 2025 to December 31, 2025 and fiscal year period July 1, 2024 to June 30, 2025, all dates inclusive.
FIRE SEASON
The fire season of 2025 began with an early start in January, when a nearly 2025 _ Season
1-acre fire, burning through a grassy south slope pine stand was reported near the
mouth of Big Creek in the Clearwater River drainage. This human caused fire was the Lightning Fires 26
first of three that would occur prior to the official start of fire season, highlighting the Lightning Acres 20.02
carelessness of man and our precipitously changing fire season in Idaho. Percent Of Total Fires 57%
Percent Of Total Acres 44%
These fires were a precursor to what would be, compared to the 40-year -
average, a below normal fire season in terms of occurrence. Finishing the season with Human Caused Fires 20
just 46 fires and 31 false runs,the C-PTPA fire season began January 22"d and Person Caused Acres 25.00
concluded with the last fire being called out on October 17th. Percent Of Total Fires 43/D
Percent Of Total Acres 56%
Fire occurrence is only part of the story, however. Energy release Component Total Fires 46
ratings for the Association district breached the 80th percentile late in May and, by and Total Acres 45.02
large, remaining at or above through mid-September with a staccato of peak ratings Average Acres Per Fire 0.98
above the 90th and 97th percentiles from early July until late August. Much of the core
fire season was spent with Smokey Bear's arm pointing to Very High or Extreme Fire Danger.
11 Hour Fuel • - 1,000 Hour FuelMoisture
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Report ot the Met Fire Warden
FIRE SEASON (Continued)
Although the fire season was not as active
as is considered average, we were able to
capitalize on many opportunities to help our
neighbors across the west and as far away as
Yukon Territory, Canada. This flexibility affords us - 1.
necessary solutions to cover budgetary shortfalls
when fire seasons at home do not align with what
was forecasted. It also provides the experience of
different topography, fuel types, fire behavior, and
suppression techniques and strategies. `
Despite conditions, C-PTPA firefighters _
were able to safely suppress all but one fire at 10 engine
acres or less, averaging less than one acre lost per •_ • _ patrolling _ Peak,ar Duncan California.
helped support initial attack in the Tahoe National Forest in 2025.
fire occurrence. This success is due to several
factors. Firstly, a robust, early fire detection network including aircraft, ground and
lake patrols, fire detection camera systems, industrial operator partnerships, and a
sharp eye of those who are keen to live near or recreate upon Idaho's magnificent,
forested landscape gives our Association a unique advantage of aggressively attacking
many of these nuisance fires shortly after their ignition. This safe, aggressive initial
attack response by our well trained, experienced firefighters is the foundation for -
keeping fires small so they are safer and less costly to suppress. Ultimately reducing
the amount of resource damage to timber values, watersheds, and communities. This
reduces the burden on state taxpayers through fiscal responsibility regarding wildfire _
suppression costs as well as protecting the resources that fund Idaho's endowment
programs. All while protecting the investments of industrial timberland owners, local Kane _ _r on assignment
tree farmers, and the small private landowners of Idaho. This has been the formulathe Yukon - • •.
for success since the Association's inception some 120 years ago.
- .- - - - - - - - -
Li htnin 26 20.02 Boehls I 9 3.86 $248,577.00 $64,398.19 $27,619.67
Recreation 1 0.70 Elk River 6 0.83 $88,383.29 $106,485.89 $14,730.55
Powerline 3 1.35 Headquarters 17 29.18 $348,226.17 $11,933.73 $20,483.89
Debris Bum 2 0.20 Orofino 14 11.15 $194,197.18 $17.416.79 $13,871.23
Arson 0 0.00 641 181 0
Equipment Use 8 5.20 - -- .. - - - .. - _ - •• -
Fireworks 0 0.00 Boehls 0 1 1
Undetermined 5 17.30 Elk River 0 5 5
Other 1 0.25 Headquarters 0 7 7
StandardsOf Protection Orofino 0 18 18
1. No more than 24 person caused fires Total
C-PTPA 2025- 20 fires Fires Land Owner AcresBurned
83.33% of allowable standard 60.9% 28 Private 1 31.86 1 70.8%
2. 97% of all fires suppressed 21.7% 10 State 7.35 16.3%
at 10 acres or less 10.9% 5 Federal 2.76 6.1%
C-PTPA 2025- 1 fire 2.2% 1 city 0.1 0.2%
2.17% of the allowable standard 4.3% 2 Tribal 2.95 6.6%
3. No more than 380 acres burned 100.0% 46 • 45.02 100.0%
3 C-PTPA 2025- 45.02 acres
12% of allowable standard
OF TOTAL

Report of the Chief Fire Warden
IMPROVEMENTS
Facilities improvements are still at top of mind as we exit the 2025 fire season. One truck shed has been rebuilt in
the headquarters camp while many others have been cleared out and evaluated for repair needs and their necessity to our
operation. Some of these buildings have become excess to our current, and long-term anticipated needs. These
dilapidated, excess sheds will be disposed of as we continue to refurbish the needed or practical ones.
The Association's initial attack fleet was also, once again, expanded this season. The addition of a new Type 6 Fire
Engine to the Elk River area will allow for the staffing of up to 6 engines by Association personnel on Association protection.
This has been a primary goal since I took the helm, officially, in 2021 and has the Association well positioned to not only
protect the resources we are commissioned over, but provide meaningful
assistance to our neighbors and interagency partners as well as out of area
training opportunities for our firefighters to continue to build the necessary
bench depth for continuing to provide the expected level of service.
Our mountaintop fire detection camera network continues to play an
integral role in our early detection of wildfires. In the 2025 fire season,the
AlertWest camera system provided initial fire detection for 6 fires on the
C-PTPA district. This is over 13%of the fires detected on Association
protection this season. Many of these were at night, when other forms of
successful detection would be impossible or highly unlikely, allowing these
fires to burn for hours until detected during the daytime by logging companies
or recreationists, causing untold damage to Idaho's natural resources. Plan-
ning has begun to add two additional cameras to the Association's protection.
One on Teakean Butte and one to replace the closed circuit, non-AI system on —
Bertha Hill. We are truly excited about the prospect of this incredible addition.
Early fire detection is critical to safe, rapid, aggressive, suppression to keep
fires on C-PTPA protection as small as safely possible. b
Current map of Alertwest carneras on Association
protection
I
Aw
l t
� •t
f
. t
4

Report of the Net Fire Warden
IMPROVEMENTS
This year we also purchased a masticating head for our Type 2 Excavator. This piece of equipment allows us to
expand our prescription of fuels treatment, provide a more efficient service, and reduce workers compensation insurance
premiums by limiting the number of hours employees spend operating power chainsaws. This equipment does this by
using a large spinning disc, much like a feller buncher, to grind and chip trees and brush into mulch, reducing the threat of
wildfire on the treated landscape.
The Association also purchased a tranche of 20 Kenwood mobile radios to continue ensuring communication
throughout our fleet. The decision to depart from purchasing a Bendix King product was made based on several factors.
First, fire agencies across the nation are already moving away from the BK brand. Secondly, support and service for BK
products has significantly declined over the last decade, leaving radios less than S years old obsolete. Third is the cost, at
nearly 300% higher, BK radios have become unaffordable based on the current replacement rates allowed by the state.
Lastly,firefighter housing is still a critical need for the Association and as we move into the upcoming year, C-PTPA
is actively considering several solutions for fulfilling this need in both the Orofino and Headquarters areas.
Type 2 excavator with masticating head
OF
Awl-
DISPATCH
Our participation in interagency dispatch continues to be a success. With proper prior planning and daily resource
status updates of initial attack resources on the district, immediate, seemingly automated, dispatch of the nearest
appropriate resources based on the day's conditions provide the rapid, aggressive response that our members expect and
demand.
Pushed by regional United States Forest Service fire leadership, consolidation of the Grangeville and Coeur d'Alene
dispatch zones is still a significant concern for the Association given the lack of reliable communication equipment currently
available to the USFS districts on the Grangeville zone. The safety of our firefighters remains the primary concern as we
continue to work with the Idaho Department of Lands, Nez Perce Tribe, Bureau of Land Management, and the USFS in
searching for a solution that recognizes and prioritizes this concern over cost savings.
5

Room of the Chief Fire Warden
ORGANIZATION, TRAINING, and PERSONNEL
Our current program, maintaining 3 full-time,year-around offices at Orofino, Headquarters, and Elk River with
a seasonal spike camp at Boehls continues to work very well.
Also, once again,the Association was fully staffed for the 2025 fire season, staffing up to 5 engines daily during
the height of fire season with a complement of 13 full-time and 33 seasonal personnel. Maintaining this level, with the
addition of the second Type 6 Fire Engine at our Elk River area will allow the ability to have 1 staffed engine available to
take interagency training assignments over the course of the summer. We currently have two Engine Boss trainees
who will be able to utilize these opportunities as we continue to build capacity within our ranks.
During the 2025 fire season, having taken advantage of these training opportunities,the Association added 1 Engine
Boss and 1 Heavy Equipment Boss qualifications.These additions will prove valuable in our fire response capabilities in
the future.
FIRE PREVENTION
During the 2025 fire season 20, or 43%, of our fires were human caused. Although this is a welcomed
departure from last year's 27 fires at 55%,this is still an unacceptably high number. More must be done to educate the
public, and where appropriate, preform wildland fuels mitigation work within the wildland urban interface. This year,
C-PTPA treated roughly 25 acres as part of a Western Fire Managers grant administered by the Twin Ridge Fire
Department. This work is an extension of previous projects completed by both the C-PTPA and the TRFD. The
execution of these fuels projects removes the need, in many cases, for private landowners to utilize prescribed fire on
their property, reducing the risk of escaped burns and additional human caused fires. This ultimately leaves more
suppression resources available to answer the call for naturally occurring wildland fires rather than expending critical,
limited resources suppressing human caused incidents. Large scale implementation of this program could significantly
reduce the number of human-caused fires in the spring and early summer season as well as provide a critical fuels
buffer, protecting homes within the WUI.
HAZARDOUS FUELS REDUCTION
As funding allows, our efforts of
hazardous fuels treatments in the wildland
urban interface will continue to grow. I look
forward to the future growth of this program,
but funding can be unpredictable as federal
administration and policies shift. One should
be cautious to avoid becoming leveraged to
support this program and should consider
alternative and ancillary uses for any
equipment purchased or personnel hired to
support it.
r«'t7-

Daily fixed wing air patrols with Association Berry Fire detected by N53083
owned aircraft once again paid great dividends. 11%
of 2025 C-PTPA fires were detected by Association air
patrols. We also provided fire detection patrols for
our neighboring IDL fire districts following high risk
weather events, detecting several additional fires on
Idaho Department of Lands protection districts.
When one considers the increased cost of
suppression, had these fires gone undetected, it is
plainly obvious that the cost of operating these small,
inexpensive aircraft for daily patrols is still easily
justified and brings great value to our members.
Evolving fire suppression strategy is creating
an environment where more and more aircraft fill the
skies above the Association and neighboring districts.
As we are now providing aerial fire detection patrols
for IDL fire districts in the Grangeville zone, it is my
recommendation that we update the current ADS-B
hardware in our primary survey aircraft, N53083, to
allow the pilot to see, track, and avoid other aircraft
nearby. This upgrade will increase the safety of pilot,
passengers, and other aircraft by no longer"flying
blind" and relying only on radio communication to
convey aircraft location, altitude, and heading.
,�. .
ti Beginning July 15`, 2025, C-PTPA again relied
on long standing relationships with local vendor
'* Hillcrest Aircraft to supply a rotor wing aircraft for T =
another 85-day, exclusive use contract for a Bell 407
Type 3 Helicopter. The fire season was an exceptional f T I
example as to why this aircraft and vendor continue to
•:�t" exceed our expectations. Multiple, vendor supplied,
fuel sources are positioned across the Association's •`"
protection at no additional cost, allowing for less time
off station for refueling when providing critical initial
attack suppression and support. The 407 continues to Y
impress with its speed, capacity, capability, and fuel
efficiency. Given the average altitude air densities and '
temperatures across the district during our typical fire
season, this aircraft consistently proves to be the right
tool for the job and although the fire season was
slower than average, the majority of the contract ,,. r,.A><,
hours were billable. The helicopter delivered a total
`•r4 of 10,390 gallons of water during fire suppression 1
7 activities. i :r
i

Report of the Met Fire Wartlen
DWORSHAK PROJECT
MT a
Y.
A
During the 52 patrols executed by the C-PTPA fire boat, there were 501 instances of documented use of
the 90 developed mini-camp sites provided by the United States Army Corps of Engineers. Over the course of
these patrols, there were no unattended campfires detected. There was one lightning caused fire that was
suppressed at just under an acre. Furthermore, during the daily patrols, the boat pilot provided initial
,±•rye detection of one fire as well as valuable information to locate several others. This patrol has proven to be a
�- valuable fire prevention tool as well as public service.
y; s
A new contract to provide services for the USACE was negotiated in the spring of 2024. This contract is
,r for five option-years and continues to provide funding for fire boat patrols, helicopter availability, and additional
options for service as needed. This also provides continued Association membership for the USACE.
Continued protection of this precariously positioned ownership remains critical to minimizing the
impacts of fire on adjacent private and state-owned industrial timberlands. USACE lands are still largely
unmanaged. This, conjugated with permitted and encouraged recreation across the ownership, continues to be
a recipe for disastrous wildland fires and great effort must continue to be taken to prevent this as we plan future
incident responses. 8

Report of the Chief Fire Warden
In closing, I would once again like to express my sincerest appreciation and recognize the credit due to our
interagency cooperators, private industrial contractors, and the dedicated staff of this fine association. Through their
commitment to duty and hard work we were able to successfully execute the Association's mission of safe, aggressive,
effective wildland fire suppression.
It is my honor to serve at the pleasure of the Board of Directors as the Chief Fire Warden of the Clearwater-
Potlatch Timber Protective Association and to present the annual report of our 1215t consecutive year of protecting Idaho's
forests.
00
M. Kane Steinbruecker
Chief Fire Warden
[ f_OVA,
, • /
- _f
9 -- - • -•.

Landowners and Acres Protected
Landowner • . -
PotlatchDeltic Corporation 420,145
State of Idaho—Department of Lands 267,739
Empire Lumber Co. 1,898
Corps of Engineers 29,318
Small Private Landowner 144,200
U. S. Forest Service 96,641
B.L.M. Lands 5,687
Tribal Lands 5,687 I I
,Total .- Acres Protected 971,315
U.S. Army Corps
of Engineers®
EMPIRE
o • s - .P
267,739 acres
f r A
j Small Private
Landowner
144,200 acres `
APotlatchDelfic-
420,145 acres
♦ s s

Acreage and Assessment of Members
7l1/2024 to 6/30/2025
Member Acreage Assessment
Empire Lumber Company 1,898 $1,138.80
PotlatchDeltic Corporation 420,145 $252,087.00
*State of Idaho 370,612 $222,367.38
Federal Agencies 01 0
Corps of Engineers 29,318 $44,270.18
**Small Private Landowners 144,200 $170,748.28
932,170 $690,611 .64
Assessment Levied 7/1/2024
*State of Idaho includes Federal Agencies
**Small Private Landowners are assessed $.60 per acre of timber, plus $40 per improved
parcel. This money is collected by the State of Idaho and remitted to the Association.
•r' '.ram
t y � _ �I'� � • mot•, •.<_. J:�t
11

Balance Sheet - June 30, 2025
Assets
Current Assets:
Cash and Cash Equivolents $3,540,258
Accounts Receivable $64,862
Unbilled Work in Process
Inventory $133,434
Prepaid Expenses
Total Current Assets $ 852,472,
Net Property and Equipment:
Construction in Progress $214,624
Property and Equipment
Less Accumulated Depreciation
Right-Of-Use Lease Asset $20,082
Less Accumulated Amortization
Net Property and Equipment $1,273,646
Other Assets:
Cash With Donor Restrictions $91,602
Accounts Recivable With Donor Restrictions 0
Total Other Asset •
Total Assets
Liabilities
Current Liabilities:
Accounts Payable $22,435
Accrued Payroll $110,953
Payroll Taxes Payable $16,572
Accrued Vacation
Retiree Insurance $56,227
Deferred Revenue
Right-Of-Use Lease Liabilities -Current Portion $3,092
Total Curent Liabilities
Noncurrent Liabilities:
Right-Of-Use Lease Liability-Less Current Portion $6,356
Total Liabilities $269,064
Net Assets:
With Donor Restrictions $91,602
Without Donor Restrictions $4,857,054
Total Net Assets $4,948,656
12
Total Liabilities and Net Assets

2025 Fires
Date Incident Name Number Area Size Fire Class Fire Cause Srecifc Landowner
1/22/202S Big Creek DCTS-029 =01.M 0.70 B Campfire BLM $19,352.10 46.4103 116.1850
3/31/2025 Cardiff IDCTS-057 HQ 0.10 A Electrical transmission/distribution systems Private $978,22 46.5776 115.8090
5/9/2025 bandoned Camp Fire IDCTS-121 OR 0.10 A Unknown State $6,560.20 46.5930 -116.3590
6/17/2025 Preacher's Saddle IDCTS-219 BC 0.10 A Machine pile/slash Private $19,531.37 46.8652 -116.0050
6/25/2025 Crooked Whiskey IDCTS-241 OR 0.10 A Unknown State $22,227.20 46.5674 -116.0350
6/26/2025 Lower Lolo IDCTS-249 HQ 0.25 A Electrical transmission/distribution systems Tribal $17,712.27 46.3728 -116.1720
6/27/2025 Weaver Creek IDCTS-251 HQ 4.00 B Heavy equipment&implements Private $94,543.89 46.4061 -115.7990
7/1/2025 Cedar Flat IDCTS-262 OR 0.10 A Origin destroyed Private $3,148.72 46.5290 -115.9930
7/3/2025 Pierce View Point IDCTS-282 HQ 0.10 A Lightning Private $10,510.02 46.4839 -115.8030
7/6/2025 Grouse Pile IDCTS-316 HQ 0.10 A Hand pile/slash Private $8,466.12 46.3170 -115.9500
7/13/2025 Fords Structure IDCTS-366 OR 0.10 A Passenger vehicle/motorized RV City $4,588.78 46.4725 -116.2460
7/14/2025 Sourdough IDCTS-371 ER 0.10 A Heavy equipment&implements Private $26,127.67 46.8112 -116.0050
7/16/2025 Bear IDCTS-383 ER 0.10 A Heavy equipment&implements Private $24,339.69 46.6633 -116.1100
7/16/2025 Cedar Larch IDCTS-384 OR 0.25 A Hot work:welder/grinder/torch/cutter Private $4,200.28 46.6613 -116.4560
7/17/2025 Bed Bug IDCTS-389 OR 0.25 A Other Private 55,882.02 46.6413 -116.4210
7/18/2025 Johnson Powerline IDCTS-395 HQ 1.00 B Electrical transmission/distribution systems Private $31,684.23 46.3916 -115.9290
7/29/2025 Spur 1 IDCTS-476 OR 0.10 A Heavy equipment&implements Private $10,947.10 46.6813 -116.3180
7/31/2025 Shattuck IDCTS-485 ER 0.10 A Lightning Private $30,981.43 46.8302 -116.2210
8/1/2025 Reed IDCTS-496 HQ 0.33 B Lightning Private $46,628.64 46.6247 -115.9040
8/1/2025 McKinnon Ride IDCTS-500 OR 1.30 B Lightning Private $28,772.73 46.5957 -116.0520
8/1/2025 Butte IDCTS-504 HQ 0.10 A Lightning Private $20,254.56 46.5980 -115. 8810
8/1/2025 Christmas IDCTS-505 HQ 10.00 C Lightning Private $226,309.49 46.6045 -115.9700
8/1/2025 Trapper Creek IDCTS-509 HQ 0.25 A Lightning Private $34,526.34 46.6437 -115.6720
8/1/2025 Riverview IDCTS-513 HQ 0.10 A Lightning Private $4,065.16 46.7065 -115.9980
8/1/2025 Shanghai IDCTS-518 HQ 0.10 A Lightning Private $11,385.43 46.5144 -115.7970
8/2/2025 No See Um IDCTS-534 BC 0.10 A Lightning Private $67,114.36 46.8530 -115.9400
8/2/2025 Robinson Creek IDCTS-535 ER 0.18 A Lightning Private $44,901.60 46.8231 -115.9930
8/3/2025 Mosquito IDCTS-539 BC 0.93 B Lightning COE $40,680.82 46.8594 -115.9180
8/3/2025 Isabella Point IDCTS-542 ER 0.25 A Lightning Private $37,263.88 46.8898 -116.0220
8/5/2025 Lower Pinchot IDCTS-567 BC 1.40 B Lightning State $93,099.30 46.9741 1-115.9280
8/5/2025 Timber Creek IDCTS-570 BC 0.10 A Lightning State $31,470.12 46.9943 -115.8950
8/8/2025 O'Donald Creek IDCTS-599 BC 0.10 A Lightning State $27,509.12 46.9860 -115.8820
8/8/2025 Pinchot Butte IDCTS-607 BC 0.10 A Lightning USFS $11,539.04 46.9847 -115.9390
8/12/2025 Gold IDCTS-637 ER 0.10 A Heavy equipment&implements Private $10,486.58 46.7635 -116.0530
8/18/2025 Crystal Ridge IDCTS-685 HQ 0.45 B Heavy equipment&implements Private $48,377.93 46.6179 -115.6900
9/1/2025 Berry IDCTS-744 OR 5.00 B Under investigation State $129,111.70 46.4971 -116.1270
9/8/2025 Evergreen 2 IDCTS-812 OR 0.10 A Lightning Private $9,334.30 46.4825 -116.1590
9/8/2025 Stony IDCTS-817 BC 0.65 B Lightning USFS $138,926.62 46.9666 -116.1050
9/8/2025 Ore Creek IDCTS-822 OR 0.25 A Lightning State $49,705.50 46.5908 -116.2060
9/8/2025 Cold Creek IDCTS-827 HQ 0.10 A Lightning State $15,593.59 46.6754 -115.9720
9/8/2025 Brown IDCTS-837 OR 2.70 B Lightning Tribal $7,112.91 46.5273 -116.3620
9/9/2025 Petri IDCTS-840 HQ 0.10 A Lightning State 510,405.18 46.6748 -115.9590
9/10/2025 Dream Weaver IDCTS-852 HQ 0.10 A Lightning Private $25,537.89 46.4341 -115.7690
9/11/2025 Dent IDCTS-870 OR 0.10 A Lightning State $52,352.69 46.6040 116.1270
9/26/2025 1 West Pinchot IDCTS-935 BC 0.38 B Lightning USFS $42,655.84 46.9878 115.9610
9/30/2025 Scoalfield IDCTS-941 HQ 12.00 C Under investigation Private $71,721.85 46.6828 115.7520
Orofino '•" '
14 fires

40 Year Fire History
.. 1 - E Fires
.. acres1986 172 0.0 0 0.0 43 92.3 10 176.0 2 254.0 1 427.0 1 1,438.0 229 2,387.3
1987 77 0.0 0 0.0 19 21.0 0 0.0 0 0.0 0 0.0 0 0.0 96 21.0
1988 97 0.0 0 0.0 15 28.5 2 64.0 2 228.0 0 0.0 0 0.0 116 320.5
1989 0 0.0 182 0.0 20 32.0 0 0.0 0 0.0 0 0.0 0 0.0 202 32.0
1990 0 0.0 90 4.1 14 24.3 0 0.0 0 0.0 0 0.0 0 0.0 104 28.4
1991 0 0.0 95 10.6 16 23.8 0 0.0 0 0.0 0 0.0 0 0.0 111 34.3
1992 0 0.0 124 13.7 25 38.8 1 50.0 0 0.0 0 0.0 0 0.0 150 102.5
1993 0 0.0 34 3.7 2 2.5 2 40.0 0 0.0 0 0.0 0 0.0 38 46.2
1994 0 0.0 234 30.7 104 185.1 9 144.5 0 0.0 0 0.0 0 0.0 347 360.2
1995 0 0.0 43 6.1 8 13.8 0 0.0 0 0.0 0 0.0 0 0.0 51 19.9
1996 0 0.0 58 8.3 17 20.4 1 20.0 1 230.0 0 0.0 0 0.0 77 278.7
1997 0 0.0 33 3.7 7 14.1 2 51.0 0 0.0 0 0.0 0 0.0 42 68.8
1998 0 0.0 78 8.5 6 12.0 2 46.0 0 0.0 0 0.0 0 0.0 86 66.5
1999 0 0.0 61 8.1 11 20.7 0 0.0 0 0.0 0 0.0 0 0.0 72 28.9
2000 0 0.0 34 4.1 8 15.1 0 0.0 0 0.0 0 0.0 0 0.0 42 19.1
2001 0 0.0 57 7.8 13 17.8 0 0.0 0 0.0 0 0.0 0 0.0 70 25.6
2002 0 0.0 33 4.4 7 13.1 2 41.0 0 0.0 0 0.0 0 0.0 42 58.5
2003 0 0.0 28 3.7 5 7.2 1 31.7 0 0.0 0 0.0 0 0.0 34 42.6
2004 0 0.0 63 7.2 6 12.4 1 19.2 0 0.0 0 0.0 0 0.0 70 38.8
2005 0 0.0 14 2.0 4 21.0 1 26.0 0 0.0 0 0.0 0 0.0 19 49.0
2006 0 0.0 101 14.7 10 15.0 1 34.0 0 0.0 0 0.0 0 0.0 112 63.7
2007 0 0.0 32 4.6 16 38.9 3 76.5 0 0.0 0 0.0 0 0.0 51 120.0
2008 0 0.0 25 3.6 11 13.8 1 90.0 0 0.0 0 0.0 0 0.0 37 107.4
2009 0 0.0 34 3.7 6 5.0 0 0.0 0 0.0 0 0.0 0 0.0 40 8.7
2010 0 0.0 19 2.1 8 17.3 1 23.0 0 0.0 0 0.0 0 0.0 28 42.3
2011 0 0.0 30 4.5 12 17.3 0 0.0 0 0.0 0 0.0 0 0.0 42 21.8
2012 0 0.0 31 3.5 10 23.0 1 80.0 1 310.0 0 0.0 0 0.0 43 416.5
2013 0 0.0 49 6.9 16 23.5 2 102.3 1 110.0 0 0.0 1 1,100.0 69 1,342.7
2014 0 0.0 70 10.7 11 18.8 0 0.0 0 0.0 0 0.0 0 0.0 81 29.5
2015 0 0.0 38 6.6 11 8.0 1 40.0 0 0.0 1 689.0 1 1,750.0 52 2,493.6
2016 0 0.0 28 3.8 4 12.4 1 15.0 0 0.0 0 0.0 0 0.0 33 31.2
2017 0 0.0 17 2.8 4 15.0 0 0.0 0 0.0 0 0.0 0 0.0 21 17.8
2018 0 0.0 28 3.8 13 15.9 2 58.7 0 0.0 0 0.0 0 0.0 43 78.4
2019 0 0.0 31 3.8 5 11.2 2 50.6 0 0.0 0 0.0 0 0.0 38 65.6
2020 0 0.0 16 1.6 6 19.3 2 61.0 1 110.0 1 499.0 1 1,631.0 27 2,321.9
2021 0 0.0 36 4.3 27 57.4 8 284.0 0 0.0 1 808.0 4 8,714.0 76 9,867.7
2022 0 0.0 49 6.1 5 12.5 1 11.5 0 0.0 0 0.0 0 0.0 55 30.1
2023 0 0.0 16 1.8 14 26.7 4 171.0 1 149.0 0 0.0 0 0.0 35 348.4
2024 0 0.0 34 4.1 14 28.8 1 33.0 0 0.0 0 0.0 0 0.0 49 65.9
2025 0 0.0 32 4.2 12 18.8 2 22.0 0 0.0 0 0.0 0 0.0 46 45.0
• / • 1 • :• 1 • Ow Rol MEEMMANII • 1 • • •
TotalFires Acres
Size Class Code Total Total
(5)Spot 346 8.7 11.6% 0.0 0.0 0.0%
(A) .25 or less _ 1,977 49.4 66.4% 223.3 5.6 1.0%
(B) .26through 9.9 565 14.1 19.0% 1,014.1 25.4 4.7%
(C) 10 through 99.9 67 1.7 2.3% 1,862.0 46.6 8.6%
(D) 100 through 299.9 91 0.2 0.3% 1,391.0 34.8 6.5%
(E) 300through 999.9 4 0.1 0.1% 2,423.01 60.6 11.2%
(F) 1000through 4999.9 8 0.2 0.3% 14,633.0 365.8 67.9%
Total2,976 74.4 100.0% 538.7 100%
14
A

Fire Occurrence Comparison
I Lightning Human
120 Year Average 69.93 34.98
12025 Fire Season 26 20
120 Year Fire Occurrence
ANEW
8,391
66.66%
Other 0.18
Lightning - ! 69.93
Miscellaneous 7:1 11.52
Children 1 0.43
Railroad 3 2.08
Equipment Use 1.95 120 Year Fire Average
Arson 3.35 BY cause
Debris Burning 6.39
Smoking 4.76
Campfire 4.33
0 20 40 60 80
1,382
10.98%
767
519 571 6.09%
4.12% 4.54% 402
3.19% 234 250
1.86% 1.99% 51 21
0 41% 0.17%
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Air lane Usage on Fires
FOrp
Program Cessna185(N53083 SuperCub N1678P) To- . 11. Engineers 1 111 111
Maintenance 1 1 11 1 11
IDL Detection 71 1 11 1 1
!Suppression 21 11 1
Total Hours 437.5 0.00 437.50
1914 White truck still in use for fire prevention. This truck is featured in many local parades along with Smokey Bear,
Elk River 1963 ierce 2025
.y 4
��
.100

Burn Permits 2025
•_ of Burn Permit •
tal
Crop Residue, Pasture, and CRP Burning 56
Weed control along ditch banks and fence lines 0
Rangeland (not cultivated or seeded in the last 10 years) 1
Prescribed Burning—broadcast 0
Burn Barrel (Residential Solid Waste Disposal) 94
Residential Yard Waste/Small Slash Piles (Max size 5 feet high 5 feet wide) 187
Medium Slash Piles (Maximum pile size 10 feet high and 10 feet wide) 12
Large Slash Piles (Piles larger than 10 feet high and 10 feet wide) 4
Hazard Management
The operating agreement between the State of Idaho and the Clearwater-Potlatch Timber Protective
Association for the management of fire hazards resulting from commercial harvest was continued in
2025.
r
Cooperative Agreement
A cooperative agreement continues to this date between the Association and the State Board of Land
Commissioners through the Director of the Idaho Department of Lands. The purpose of this
agreement is to clarify the forest protection relationship between the Association and the Idaho
Department of Lands. It defines the reimbursable emergency fire suppression expenditures that may
be incurred by the State and Association. In addition, the agreement addresses the following:
(1) fire protection plans, (2) fire management, (3) reports and records, (4) budgets, (5) administrative
matters, (6) payments, (7) duration, and (8) limited obligation by the State. ,a ,

Monthly Precipitation Comparison 2025
Taken at Elk River, Idaho
IMay June July August I September October
Rainfall (inches) 0.87 0.18 0.34 1.09 1.22 2.26
72 yr average 2.43 2.17 0.84 1.04 1.63 3.73
Departure From Ave. -1.56 -1.99 -0.50 0.05 -0.41
Taken at Headquarters, Idaho
J ne July August September October
Rainfall (inches) 1.76 1.08 0.7 1 1.72 3.26
80 yr average 2.83 2.74 1.22 1.35 1.87 2.77
Departure From Ave. -1.07 -1.66 -0.52 -0.35 -0.15 0.49�
Log Production 2025
'Total log production from operators holding agreement under Surety Bond 217,819.35 MBF >. I
'Total log production from operators under Holdback Option 2: 4,046.62 MBF
S
'Total log production from operators under Option 1: 28.82 MBF
Total: 221,894.79 MBF
18

Fire Locations 2025
Timber C 6
West Pinchot♦ O'Do Cr-k
Plnchot Butto Lower Pinchot
Stony
Boehl's Camp
Isabella Point
Preachers Saddle
Mosquito
M,n No See Um
Shattuck
Robinson Creek
Sourdough
Elk River
Elk River Camp* Gold
Riverview
Spur 1 Scoalfield
♦ Cold Creek Petri
Cedar Larch Bear
Trappe cf"k
♦Bed Bug Headquarter's •
Reed
Camp Crystal Rid c
Dent Christmas
Abandoned Camp Fire Ore Creek McKinnon Ridgs Butte
s
Cardiff
Crooked Whiskey
Brown Flat
♦ Shanghai
♦
Be"
Orofino Office Evergreen �I —Point
OroO •
Peck Fords Structure
Dream Weduc,
Big Creek Weave Creek
Johnson Powerline
Lower Lolo Welppe
'• Grouse Pile
S
19

Fire Locations 2016-2025
BoehI's Camp•
w iil
m -
2
♦ Elk River •
*Elk River Camp
• ° Headquarter's °
• Camp
*
• • ♦♦ Plate
Orofino Officq,,,,••
Peek • •
•
• •.... • •,♦WdPPq •
10 Year totals
Fires Acres
•♦ s •s
368 1 12,871.82 .►
• ♦ �♦ 20
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