20190304PAC to IIPA Dave Johnston FINAL P-DJD002.pdf

PacifiCorp
Dave Johnson Generating Facility
Demolition Study
Date of Issue: August 15, 2014
Revision: 1
Table of Contents 1.0 DECOMMISSIONING AND DEMOLITION SEQUENCING 3
1.1 Decommissioning 3
1.1.1 Investment Recovery - Sold Assets 3
1.1.2 Pre-Mobilization Activities Prior to Plant Demolition 4
1.1.3 Pre-Construction Meeting 4
1.2 Dave Johnston Generating Station Demolition 5
1.2.1 Task 1: Pre-mobilization Plans, Submittals and Permitting 6
1.2.2 Task 2: Demolition Contractor Mobilization 6
1.2.3 Task 3: Site Setup, Install Erosion Control Measures, Utility Cut and Cap 7
1.2.4 Task 4: Water Intake Pipes Plug and Grout 7
1.2.5 Task 5: Close the Coal Pile – Remove All Waste Coal, Minimize backfill, Grade and Seed 8
1.2.6 Task 6: Dismantle All Outer Structures, Admin Building, Support Buildings, Coal Conveyors, Crusher
house, Scrubber Building Precipitators 8
1.2.7 Task 7: Dismantle the Turbine Generators 9
1.2.8 Task 8: Dismantle Turbine Generator Building 10
1.2.9 Task 9: Prepare Boiler Structure for Implosion; Implode Boiler House Structure Units 1-4 11
1.2.10 Task 10: Dismantle Stacks 11
1.2.11 Task 11: Prepare and Process Steel, Load and Salvage 12
1.2.12 Demolition Scope General Conditions - Administration 12
1.3 Plant Demolition Cost Detail 15
1.4 Stack Demolition Cost Detail 16
1.5 Schedule 17 2.0 ENVIRONMENTAL 18
2.1 Asbestos Abatement 18
2.2 Environmental Permits/Plans 18
2.3 Hazardous and Universal Waste Disposal 18
2.4 Pond Closure 19
2.5 Landfill Closure 20
2.6 Remediation of Contaminated Soils and Groundwater 20
3.0 SALVAGE 21
3.1 Materials by Category 22
3.1.1 Structural Steel and Rebar 22
3.1.2 Boiler Material 22
3.1.3 Heat Exchangers 22
3.1.4 Rotating Equipment 23
3.1.5 Turbine/Generator Set 23
3.1.6 Cabling 24
3.1.7 Piping and Valves 24
3.1.8 Transformers 24
3.1.9 Tanks and Ductwork 24
3.1.10 Spare Parts 24
3.2 Market Analysis of Salvage Prices 25
3.3 Salvage Estimate 27
3.4 Analysis of Transportation 28
4.0 SUMMARY OF COSTS 29

1.0 Decommissioning and Demolition Sequencing
The following section presents an overall suggested project sequencing approach for the
decommissioning and demolition of the Dave Johnston Generating Station in its entirety. It has been
assumed that complete demolition of the Dave Johnston Station will be performed down to concrete slabs
and foundations to two feet below existing grade. For the purposes of this engineering estimate,
demolition includes the razing of all structures associated with the plant down to and includes removal of
the existing slab and above grade concrete. Demolition of the plant will not take place at Dave Johnston
until all project plans are assembled, reviewed and approved. Typically, a demolition permit can only be
issued once asbestos abatement and environmental work has been completed and final inspections are
performed prior to the start of deconstruction activities.
1.1 Decommissioning
Decommissioning of the plant is defined as placing the plant in an environmentally neutral, zero-energy
state. This requires the removal of all hazardous and waste materials that could result in a release during
plant dismantlement. This includes materials such as lubricating fluids/oils, fuel oil, coal combustion
residuals, PCBs, ACM, lead paint, process chemicals, and universal wastes including mercury
switches/mercoids.
Utility cut and cap activities, completed in accordance with PacifiCorp and Dave Johnston Station lock
out/tag out program requirements (short term measure) and air gapping procedures (long term measure),
would also be completed and verified during the decommissioning project phase. The estimated cost
associated with the demolition phase of the plant begins with the pre-mobilization submittals. The utility
cut and cap phase is part of the demolition site setup phase of the plant. It is assumed that the demolition
contractor will work closely with plant electrical personnel in affecting the de-energizing of the plant
prior to the onset of demolition activities. The transmission assets will remain operational and in place
since they are owned by PacifiCorp Transmission. The costs included are assumed in this estimate to
include removal of transmission lines that enter the plant back to a pre designated transmission supporting
structure far enough away from the power block structure to allow for safe dismantlement activities. The
estimate at this time does not include the cost to reconnect the transmission lines once removed. It is
recommended that additional due diligence be performed to finalize the logistics required for the re-
connection to maintain the transmission assets in an undisrupted and operational order throughout plant
decommissioning and dismantlement.
1.1.1 Investment Recovery - Sold Assets
Any assets sold by the Plant or its designees would be removed from the power house utilizing small
forklifts and the existing overhead (OH) cranes, if applicable, prior to demolition. It is assumed that these
cranes will be energized using existing facility power or a temporary power loop installed for the project.
Cranes will require re-certification by a qualified crane inspection/certification company prior to use. Sold
assets will be moved to the truck/rail bay via the OH crane(s) and loaded on customer trucks if
coordination allows or loaded on the demolition contractor’s trailers for transfer to plant approved staging
area. The turbine generators will be removed during demolition of Turbine Hall using the existing gantry
cranes when dismantlement of the plant begins.
Any contractor who intends to remove an item of equipment must provide a rigging plan and in some
cases, an asbestos abatement plan to Dave Johnston Station oversight personnel for review and final
approval. Limits on the removal of ancillary wiring and piping must also be overseen to avoid excess
removal of salvageable materials.
1.1.2 Pre-Mobilization Activities Prior to Plant Demolition
Prior to initiation of demolition activities the following project plans and submittals would be required:
1. Demolition & Dismantlement Execution Plan
2. Application for all Permits including in accordance to the Final Permitting Matrix
3. Site Specific Health and Safety Plan
4. Scrap/Salvage Materials Management Plan
5. Waste Management Plan
6. Utility Cut and Cap Plan
7. Erosion and Sediment Control Plan
8. Quality Control Plan
9. Sampling and Analytical Plan (if necessary for Basin/impoundment closures)
10. Preparation and finalization of a final CPM project schedule;
The demolition permit will be the primary permit vehicle governing the planned work. The final project
design package, including the technical specifications and drawing package will be utilized to support the
Demolition Permit application package. This permit is issued by the State of Wyoming and local
municipality.
It is noteworthy that the Dave Johnston Engineering Division at the plant has many drawings and
environmental information that are well organized and will be indispensable for use in the preparation of
the demolition design and specification package prior to procurement of an environmental remediation or
demolition contractor.
1.1.3 Pre-Construction Meeting
Prior to commencement of site activities a pre-construction meeting will be held at the Dave Johnston
Generating Station. This meeting will be attended by all project stakeholders, including but not limited to
the following:
a) Dave Johnston Generating Station Project Manager and Corporate Sponsor;
b) Dave Johnston Generating Station Technical Leads;
c) Dave Johnston Generating Station managers and key operations staff;
d) Engineer’s demolition project design team;
e) Engineer’s construction management team;
f) Demolition Contractor Project Managers/Superintendents
The primary purpose of this meeting will be to communicate all project objectives to the project team,
define project safety as the primary project objective, complete a detailed review of the project plans,
scope of work, technical specifications, schedule, introduce key project staff, and establish the reporting
requirements for the project.
1.2 Dave Johnston Generating Station Demolition
An integral part of the valuation of the Dave Johnston Generating Station in Glenrock, WY is to demolish
the plant in order to obtain access to the salvageable assets from the facility. Demolition represents the
cost to access all salvageable revenue and is therefore an inherent component of cost while salvage in the
form of recyclable metal represents one revenue stream in the economics of this valuation.
The following sections describe the means and methods that were developed during the site visit
conducted at the plant on June 8, 2014 to develop a demolition approach for this site. The overall
Sequence of work for dismantlement is as follows:
•Pre mobilization plans, permitting, submittals and final approvals
•Mobilization of all labor, equipment and materials
•Site setup, install erosion control measures and commence utility disconnections and cut and caps
including protection of transmission assets as required by the Interconnection Agreement
•Water intake and discharge pipes plug and grout
•Coal pile closure – remove all waste coal, minimal backfill, grade and seed
•Dismantle all outer structures, crusher house, baghouse, scrubber buildings, tanks (above ground)
coal handling equipment, precipitators, and silos
•Dismantle the turbine generators
•Dismantle turbine generator building
•Prepare the boiler house structures for implosion, implode structure units 1-4
•Dismantle stacks by munching down method
•Dismantle the cooling towers
•Prepare and process steel on site
•Load and ship salvage by truck, rail or barge
•Reclaim and restore the site and remaining basins
Facility demolition will take approximately 400 calendar days to complete. The sequencing of the work
will be performed in accordance with the Demolition Schedule. The approach used in the dismantlement
of the plant will start with the outer buildings first. This allows for a safer and more effective access to the
taller structures such as the boiler house and turbine hall structures. The boiler house structure will be the
final above grade structure to be dismantled and it is anticipated that this structure would be safer to take
down by implosion once all of the outer structures have been physically removed. The estimate assumes
that the transmission lines and yards will be de-energized during decommissioning by Dave Johnston
Station personnel. For the purposes of this estimate, equipment such as transmission lines and
transformers are assumed to be removed, relocated and/or protected. Additional planning will be required
to remove any transmission assets from the power block (i.e. the turbine hall wall) to allow for
dismantlement either by mechanical means or by implosive methods. The protection of the transmission
assets must be accounted for in all implosive modelling efforts. These assets include the associated
grounding grid and fencing during the entire demolition phase of work.
1.2.1 Task 1: Pre-mobilization Plans, Submittals and Permitting
Prior to mobilization, an integral step must be taken where all plans and submittals are prepared by the
selected demolition contractor and provided to the oversight engineer for review and approval. The plans
must be approved by the oversight engineer for submittal, review and approval to local and State
regulatory entities for the acquisition of the demolition permit. Four weeks were allocated for this
process. These plans specific to the demolition scope of work are anticipated to be as follows:
• Demolition / Construction Execution Plan
• Site specific Health and Safety Plan
• Implosion Work and Safety Plan
• Salvage Management Plan
• Erosion and Sediment Control Plan
• Storm Water Pollution Prevention Plan
• Remedial Action Work Plan
• Quality Control Plan
• CPM Schedule
• Final Report
1.2.2 Task 2: Demolition Contractor Mobilization
Site Mobilization is expected to take approximately fifteen (15) days. The following shows the labor and
equipment that will mobilize to the site to begin the work. The costs for management are carried under in
the General Conditions portion of the Demolition estimate found in Section 6.2.12.
Table 16 – Task 2: Contractor Mobilization - Labor and Equipment
Description Quantity/Duration
Labor
Health and Safety officer 1
Site Superintendent 1
Foremen 2
Operator 6
Laborers 7
Equipment
Manlift (80ft boom) 4
Cat 950G rubber tire loader with demo Bucket 2
Lull with Forks 2 Cat 345 Excavator with Grappler 2
Cat 345 Excavator with Grappler/Shear Attachment 2 Cat 345 Excavator with Grappler 2
Cat 345 UHD 1 Bobcat 220 Skidsteer with Solid rubber Tires 4
Water Pump for dust control 1 End dump - 25 ton 4
50-75 KW Generator 2 4WD Pickup Trucks 6
Portable toilets 4
Conex Box 2
Office Trailer 1
1.2.3 Task 3: Site Setup, Install Erosion Control Measures, Utility Cut and Cap
Site setup activities are expected to take three (3) months and are concurrent with the completion of the
utility cut and cap task and installation of the erosion control measures. Utility cut and caps are expected
to progress for six (6) to eight (8) weeks starting with any utilities associated with the boiler house, the
admin building, Turbine Hall and the utilities associated with the outer buildings. This task also calls for
the retaining of one of the plant engineers that will serve as liaison to the contractor and the plant in
assisting with providing information that may require attention in the planning stages of the project or to
guide setup activities
As part of this task, the crew will also be setting up the site office trailer, communications, preliminary
steel preparation and staging areas, site scale calibration and performing recertification of the overhead
cranes. Some of the equipment will be transported to the site on multiple trailers such as the larger
excavators, and associated attachments. The large cranes and other long reach equipment crane will arrive
when the coal conveyor and high reach duct and pipe racks are ready for dismantlement in addition to the
silos.
A critical component of the utility cut and cap program will involve all lock out tag out requirements for
the project. The selected demolition contractor and engineer must adhere to PacifiCorp Dave Johnston
Plant LOTO procedures for this work and must demonstrate that its program meets all Dave Johnston
Station, OSHA, state and local regulatory requirements.
The following table shows the labor and equipment that will mobilize to the site to begin the work.
Table 17 shows the items required for Task 3:
Table 17 – Task 3: Site Setup, Utility cut and Cap - Labor and Equipment
Description Quantity/Duration
Labor
Operator 4
Laborer 4
Foremen 2
Millwrights 4
Structural Engineer 1
Equipment
Cat 345 Excavator with Grappler 1 Cat 345 Excavator with Shear 1
Manitowoc 12000 1 Bobcat S220 Skidsteer 2
Lull forklift 2 Calibrate Scales & certify Overhead cranes 1
Manlift (80 ft. boom) 4
1.2.4 Task 4: Water Intake Pipes Plug and Grout
The plugging and grouting of the Water Intakes will be performed by installing inflatable plugs into the
intakes followed by plugging the pipes with cement below grade. All above grade portions of the intake
pipe will be removed and cut to 1 foot below grade and backfilled. The Rough Order of Magnitude
(ROM) demolition estimate budgets three (3) weeks to perform this task. The resources required for this
effort are as follows:
Table 18 – Task 4: Plug and Grout Water Intake piping, Compromise Blowdown Pipes - Labor and
Equipment
Description Quantity/Duration
Labor
Operator 2 Laborer 2
Foreman 1
Equipment
Inflatable Plug and Grout allowance 1 50 ton Crane 1
1.2.5 Task 5: Close the Coal Pile – Remove All Waste Coal, Minimize backfill, Grade and Seed
This task requires the closure of the coal pile. The estimate assumes that prior to arrival of the demolition
team most of the usable coal would be sold by the plant or mostly used up as part of plant operations. It
also assumes that the conveyor tunnel would remain in place but opened and backfilled with existing
residual material, or material from the site. All coal pile structures would be removed and the series of
coal chutes along the tunnel alignment would be removed and scrapped if possible or covered over with a
welded steel plate. The tunnels will also be removed and backfilled. Residual coal remaining over the 1,
300,000 SF area of the coal pile will be covered using about 4-6 inches of on-site material and seeded
over. This work can occur in parallel with the removal of the outer plant structures, or can be scheduled
during plant decommissioning.
The resources anticipated for this phase of the work is as follows:
Table 19 – Task 5: Coal Pile Closure - Labor and Equipment
Description Quantity/Duration
Labor
Operators 5
Laborers 4
Equipment
Cat 345 Excavator with bucket 2 Cat 345 Front End Loader 1
Cat D-5 Dozer 1
1.2.6 Task 6: Dismantle All Outer Structures, Admin Building, Support Buildings, Coal Conveyors,
Crusher house, Scrubber Building Precipitators
Task 6 begins with the removal of all out structures outside of the plant’s Power Block (i.e. outside of the
boiler and turbine structures). The compliment of Cat 345 excavators equipped with grappling
attachments will begin the dismantlement of exterior tanks the crusher house structure, the scrubber
buildings, the cooling towers, the coal conveyors and precipitators. All support buildings and those
structures associated with the emissions treatment systems will also be removed as part of this task. The
intent is to create as much room as possible around the power block for the safe implosion of the boiler
house structure. It will also create additional safe operating room for processing of all removed steel from
the first two floors of each boiler house to lighten the structure as much as possible, along with ample lay
down room for the removal of the coal conveyors which is scheduled later in the task.
Crews will be working within the power block concurrently with this task cutting and removing piping
runs, wire and plate steel. The crews will also systematically go through the boiler houses further
preparing the structure for implosion. A 100 ton crane will be on site to address the removal of this
segment of the conveyor. The crane will support the weight of this conveyor segment while two crews
perform partial cut away of this segment for lay down. The demolition work plan must address this
critical lift for this critical part of the operation.
As previously discussed, the north wall transmission line support will have to be relocated to keep these
transformers in service prior to powerhouse demolition. It is assumed that required relocation activities
will be completed prior to the initiation of demolition, and there is budget to remove the lines back to the
designated support tower well away from the Turbine Building to allow for protection of the asset during
implosive demolition/dismantlement of the Turbine Building structure.
Task 6 is anticipated to take approximately eight (8) months to complete. All scrap generated as a result
of the removal of the outer structures will be processed for loadout to the scrap recycler while general
demolition and construction debris will be transported to a local landfill. Metal scrap from the outer
structures and other associated metals will be separately staged for eventual steel recycling. Sizable
concrete (< 2 foot by 2 foot) generated from the hammering of the pedestals and silos will be staged and
reused for eventual backfill where needed. Size reduction will take place to accommodate fill use around
the site as demolition proceeds.
Table shows the estimated resources required for performing Task 6:
Table 20 – Task 6: Dismantle Outer Structures - Labor and Equipment Description Quantity/Duration
Labor
Operator 5
Laborer 4
Equipment
Cat 345 Excavator with Grappler 8 mo.
Cat 345 Excavator with Grappler/Shear attachment 8 mo.
Cat 345 Excavator with Shear 8 mo.
Cat 950 G Solid Tire Loader 8 mo.
Cat 345 Ultra High Demolition with shear/grappler Attachment 8 mo. End Dumps 8 mo.
Manitowoc 100 ton Crane 1 wk. Cat 345 Excavator with 15,000 lb. hammer 8 mo.
1.2.7 Task 7: Dismantle the Turbine Generators
Task 7 involves the dismantlement of the 4 turbines within the turbine hall structure. All associated
equipment will also be removed from the building for salvage processing to the preparation areas. The
gantry cranes within Turbine Hall should remain energized and will be re-certified for use to
accommodate removal of this equipment to open bay area of Turbine Hall. The condensers for each
turbine will also be removed. The gantry crane will lift segments of the turbines for placement onto
lowboy trucks that will remove the equipment in route for salvage preparation and/or asset sale. This task
may also involve the removal of interior asbestos material within the turbines themselves. The
buyers/contractor’s lift plan and rigging arrangements must be reviewed and approved by the oversight
engineer and plant management prior to the onset of this work. The task is expected to take 6 months to
complete. The anticipated resource requirements for this task are as follows:
Table 21 – Task 7: Dismantle the Turbine Generators - Labor and Equipment
Description Quantity/Duration
Labor
Operator 2 Laborer 7
Millwrights 3
Equipment
Front end loader with 5 cy bucket 6 mo. Cat 345 Excavator with Grappler/Shear attachment 6 mo.
Cat 345 Excavator with 75,000 lb. hammer 6 mo. Truck with Lowboy Trailer 6 wk.
1.2.8 Task 8: Dismantle Turbine Generator Building
Task 8 involves the dismantlement of the Turbine building once all of the major equipment and
appurtenances are removed from the structure. The Turbine Building Structure measures approximately
775 feet x 75 feet. A removal rate of roughly 3,000 square feet per day has been applied to this task
duration for the estimate with additional contingency. The turbine building will be dismantled up to
where the Turbine building physically meets the Unit 1-4 boiler house structure. All internal and
associated tanks will also be removed as part of this task. A crew will systematically begin the
dismantlement of the turbine hall structure and remove all steel components for the recovery of ferrous
and non-ferrous metals. The processing of these materials will take place concurrently with the removal
of all piping and no structural support steel being removed from the lower floors of the adjacent Boiler
House structure that is being performed as part of Task 9.
The dismantlement of the Turbine building is expected to take approximately 27 days to perform. Table
22 shows the resources for Task 8.
Table 22 – Task 8: Dismantle Turbine Generator Building - Labor and Equipment
Description Quantity/Duration
Labor
Operators 6 Laborers 4
Equipment
Front end Loader with 5 cubic yard bucket 1.25 mo.
Cat 345 Excavator with Grappler 1.25 mo. Cat 345 Excavator with Shear 1.25 mo.
Cat 345 Ultra High Demolition with Shear/Grapple attachment 1.25 mo.
Excavator with 75,000 lb. hammer 1.00 mo.
End dump - 25 ton 1.25 mo.

1.2.9 Task 9: Prepare Boiler Structure for Implosion; Implode Boiler House Structure Units 1-4
The preparation of the boiler house structure involves the removal of all non-structural supporting
components for processing and recycling. The purpose for the removal is to create enough void space
low in the structures to accommodate the collapse of the structure during implosion. The removal will
involve two excavators that will work exclusively in removing all ferrous and non-ferrous assets from the
lowermost floors and a high reach excavator to remove interior equipment from outside of the structure.
Labor crews equipped with torches will also work to cutaway interior equipment prior to preparing the
building for implosion. The demolition contractor and the implosion contractor will coordinate all of
these activities in accordance to the approved implosion work and safety plan. It is anticipated that 4
months will be required for this task. Table 23 summarizes the resources in the estimate for Task 9.
Table 23 – Task 9: Prepare Boiler Structure for Implosion of Units 1-4 - Labor and Equipment
Description Quantity/Duration
Labor
Operators 3
Laborers 7
Equipment
Front end loader with 5 cy bucket 4 mo.
Cat 345 Excavator with Grappler 4 mo.
Cat 345 Excavator with Grappler 4 mo.
Cat 345 Excavator with Grappler 4 mo.
Manitowoc 12000 1 mo.
Subcontractors
Implosion subcontractor 1
1.2.10 Task 10: Dismantle Stacks
This task is estimated to take approximately 2.5 months to complete. The Dave Johnston Station has four
original stacks and two newer concrete stacks. The Unit 1 through 4 stacks are approximately 220’ high,
the two concrete stacks are approximately 500’ high. Three of the four original stacks are concrete in
composition and the Unit 4 stack is metal. There are two accepted methods for removing the stacks. One
method involves hoisting a munching device to the top of each stack which eats away at the stack walls.
The other method is to shoot the stacks allowing them to freefall. Both methods are controlled methods of
removing the stacks, however the munching method of removal is time intensive and thereby more
expensive than shooting the stacks. For the purposes of this estimate, we chose to implode all of the
masonry stacks provided any Asbestos Containing Material (ACM) is abated prior to demolition. The
metal stack from unit 4 will be pulled down. The estimate presented in this valuation also presents this
task as a standalone to allow the reviewer to see the unit cost of this method. The munching method
roughly costs $375/lineal foot versus the shooting method costing approximately $275/ lineal foot. The
munch-down method of stack removal would take approximately four (4) months to complete versus half
the time to shoot the stacks. Therefore implosion of the stacks was carried in this estimate. Stack
implosion should be planned simultaneously with the implosion of the boiler houses thereby imploding
the entire structure and stacks in one event. If planned simultaneously with the implosion of the Power
Block Structure, the cost of implosion carried in this task may still represent a cost savings depending
upon complications revealed as a result of implosive demolition planning. It is recommended that a
single cost from the implosion contractor be obtained to incorporate the demolition of both the stacks and
the power block together. The resources for this task are as follows:
Table 24 – Task 10: Dismantle Stacks - Labor and Equipment
Description Quantity/Duration
Labor
Operators 5
Laborers 6
Equipment
Cat 345 with Grappler 2.5 mo. Front end loader with 5 cy bucket 2.5 mo.
Hydraulic Stack Muncher 2.5 mo. Manitowoc 12000 2.5 mo.
Subcontractor
Implosion Contractor 1 ea.
1.2.11 Task 11: Prepare and Process Steel, Load and Salvage
In essence the preparation and processing of all recyclable materials on site will be a continuous site task
throughout the project. Manpower will vary throughout the duration of the project as the processing task
evolves from the processing of material resulting from the demolition of the main plant structures to the
processing of the outer plant structures. To process material from the outer buildings and the power block
of the plant, 220 working days were allocated to process and prepare steel. An additional 50 working
days were allocated for the processing of rebar from the stacks. A total of approximately 400 to 420 days
are allocated in the ROM estimate for processing, preparation and eventual load out of all
salvageable/recyclable metal. These tasks are separately presented in the cost estimate but are
consolidated here. This task is approximate due to several factors for example, the sequencing of
dismantlement tasks that can be scheduled concurrently thus shortening the duration of the overall
schedule, space availability developed as a result of dismantlement activities, and the availability of
trucking. An estimate of the resources for this task is found in Table 26 as follows:
Table 25 – Task 11 Prepare and Process Steel; Load Salvage
Description Quantity
Labor
Operator 3
Laborer 7
Equipment
Cat Front End Loader 20 mo. Cat 345 Excavator with Grappler 20 mo.
Cat 345 Excavator with Shear 20 mo.
1.2.12 Demolition Scope General Conditions - Administration
General Conditions/Site administration is dedicated to the project for approximately 450 working days
including pre-mobilization activities. The following, shown in Table 27, resources are anticipated and
included in the demolition costs:
Table 26 – Project Resource Summary
Description QTY UOM HRS
Labor
Project Manager 1 ea. 3600
Site Superintendent 1 ea. 5120
Foreman 2 ea. 6400
Health and Safety Officer 1 ea. 2100
Project Controls 1 ea. 1580
Project Accountant 1 ea. 3520
Subcontractor Management 1 ea. 540
Structural Engineer 1 ea. 880
Mechanic with full Service Truck 1 ea. 2800
Per diems + lodging MI&E rate - $145/day for Glenrock, WY 3050 ea.
Misc. travel Expenses @ $1500 each 15 ea.
Pickup Trucks 23 mo.
Conex Box 23 mo.
50-75 KW Generator 10 mo.
Cutting Torch assembly including gases 23 mo.
Manlift (80 ft. boom) 43 mo.
Dust Boss 23 mo.
Water Truck 23 mo.
Bobcat 220 Skidsteer 24 mo.
10,000# Lull forklift 24 mo.
End Dump 25 Ton 2nd, Swing 24 mo.
Office Trailer plus block, level tie down and stairs 23 mo.
Low Value Equipment Allowance 29 ea.
Portable Toilets (4) 30 mo.
Project supplies 2 ea.
Fit testing, turnover, Medical Testing @ $400 ea. 50 ea.
Project Meetings 25 ea.
Construction Debris Disposal @$1100/load 90 Loads
Equipment FOGMA
Description QTY UOM HRS
4WD Pickup Trucks 4 ea. 4040
CAT (equiv.) D5 Dozer 1 ea. 1600
BobcatS220 Skidsteer 2 ea. 3200

The estimate for demolition assumes that all heavy equipment is based on current rental rates. CB&I
rental rates were assumed for this estimate based on national agreements with Hertz Rental Equipment.

PACIFICORP
DAVE JOHNSTON POWER PLANT, CASPER, WY
ROM ESTIMATE SUMMARY
TASK DESCRIPTION BASE COST ($)
Pre mobilization Plans and Permitting $ 43,720.00
$ 77,740.00
Site Setup and Utility Cut and Cap $ 372,620.00
Water Intake Pipes Plug and Grout $ 65,400.00
Coal Pile closure - Remove all waste Coal, Minimal Backfill Grade and Seed $ 515,400.00
Dismantle All Outer Structures, Crusher House, Scrubber buildings, Lime Handling, Tanks, Conveyors
Precipitators
$ 3,133,600.00
Dismantle Turbine Generators $ 1,350,600.00
Dismantle Turbine Generator Building $ 355,175.00
Prepare boiler Structures for Implosion, Implode
Structure Units 1-4 $ 998,600.00
(loading only, not actual shipping costs)
Administrative/General Conditions $ 5,799,070.00
SUBTOTAL $ 15,853,525.00
Process and Dismantle Stacks 1-4 $ 868,100.00
Administrative and General Conditions $ 228,085.00
SUBTOTAL $ 1,096,185.00
$ 6,027,155.00
SUBTOTAL $ 16,949,710.00
MARKUP OF 8% $ 1,355,976.80
GRAND TOTAL $ 18,305,686.80

QTY UOM HRS RATE SUBTOTAL
Site Superintendent 1 ea.40 75.00$ 3,000.00$
Structural / Engineer 1 ea.40 100.00$ 4,000.00$
Health and Safety 1 ea.20 60.00$ 1,200.00$
Civil Engineer 1 ea.30 80.00$ 2,400.00$
Administrative Assistant 1 ea.20 31.00$ 620.00$
Mass LSP 1 ea.50 100.00$ 5,000.00$
Plans QTY UOM HRS RATE SUBTOTAL
Implosion Work and Safety Plan Subcontractor 1 LS 1 15,000.00$ 15,000.00$
Salvage/Asset Management Plan 1 LS 1 2,000.00$ 2,000.00$
Erosion and Sediment Control Plan 1 LS 1 2,500.00$ 2,500.00$
Demolition/Construction Execution Plan 1 LS 1 2,500.00$ 2,500.00$
Health and Safety Plan 1 LS 1 2,500.00$ 2,500.00$
Permits QTY UOM HRS RATE SUBTOTAL
General Construction Permits Allowance 1 LS 1 3,000.00$ 3,000.00$
43,720.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 6 ea.24 80.00$ 11,520.00$
Laborers 7 ea.24 80.00$ 13,440.00$
Equipment (Mobe and Demobe is 1 event)QTY UOM HRS RATE SUBTOTAL
Manlift (80' boom)2 ea.2 1,200.00$ 4,800.00$
Cat 950G rubber tire loader with demo Bucket 2 ea.1 1,500.00$ 3,000.00$
Lull Forklift 2 ea.1 1,200.00$ 2,400.00$
Cat 345 Excavator with Grappler 2 ea.1 4,000.00$ 8,000.00$
Cat 345 Excavator with Grappler/Shear attachment 2 ea.1 4,000.00$ 8,000.00$
Cat 345 Excavator with Grappler attachment 2 ea.1 4,000.00$ 8,000.00$
BobcatS220 Skidsteer 4 ea.1 500.00$ 2,000.00$
End dump - 25 ton 4 ea.1 1,000.00$ 4,000.00$
50-75 KW Generator 2 ea.1 300.00$ 600.00$
4WD Pickup Trucks 6 ea.1 30.00$ 180.00$
Portable toilets 4 ea.1 200.00$ 800.00$
Conex Box 2 ea.1 1,000.00$ 2,000.00$
Office Trailer 1 ea.1 1,000.00$ 1,000.00$
Cat 345 UHD with attachment 1 ea.1 8,000.00$ 8,000.00$
77,740.00$
Labor QTY UOM HRS RATE SUBTOTAL
Plant Engineer 1 ea.120 100.00$ 12,000.00$
Operators 4 ea.480 56.00$ 107,520.00$
Laborers 4 ea.480 40.00$ 76,800.00$
Millwrights 4 ea.40 80.00$ 12,800.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 345 Excavator 3 month 1 25,500.00$ 76,500.00$
Cat 345 Excavator with shear 3 month 1 25,500.00$ 76,500.00$
Manitowoc 12000 1 ea.150 70.00$ 10,500.00$
ODC QTY UOM HRS RATE SUBTOTAL
Allowance for Shallow subsurface line removal 1 ea 1 50,000.00$ 50,000.00$
2 month = 20 working days
2 day = 8 hours
2 week = 40 hours
Assumes all lines are dead or de-energized
There are many subsurface utilities on the main plant property
Three crews will perform the cut and caps. Equipment is already on site.
Task does not include retaining of transmission line representative for line removal off of TH wall
Most terminations will be done on plant floor drains. Underground fuel lines will be pulled near the vessel and plugged but not removed from the subsurface unless accessible
All piping will be located and capped 1-2 foot below surface. If fuel line, the lines will be flushed and capped and left in place.
An additional $50,000 allowance is added to handle line and conduit removal for subsurface piping shallower than 2 feet below grade
Reconnection of trans lines to be by others.
The transmission asset detachment from turbine bldg wall will occur in this task. Trans lines to be moved off Turbine Hall wall to nearest dead end structure to allow for implosion
SECTION 1.3 Detailed Cost Estimate
Labor QTY UOM HRS RATE SUBTOTAL
Operators 2 ea.120 $80.00 $19,200.00
Laborers 2 ea.120 $80.00 $19,200.00
Equipment QTY UOM HRS RATE SUBTOTAL
50 ton crane 10 days 1 $1,200.00 $12,000.00
Plug allowance 1 ea 1 $15,000 $15,000.00
$65,400.00
Labor QTY UOM HRS RATE SUBTOTAL
Operators 5 ea.320 80.00$ 128,000.00$
Laborers 4 ea.320 80.00$ 102,400.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 345 Excavator 2 month 2 25,500.00$ 102,000.00$
Cat front end Loader 2 month 1 25,500.00$ 51,000.00$
Cat D5 dozer 2 month 2 25,500.00$ 102,000.00$
ODC QTY UOM HRS RATE SUBTOTAL
Seeding allowance 1 ea 1 25,000.00$ 25,000.00$
Grade Survey 1 ea 1 5,000.00$ 5,000.00$
515,400.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 5 ea.1280 80.00$ 512,000.00$
Laborers 4 ea.1280 80.00$ 409,600.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 345 Excavator with Gappler 8 month 2 25,500.00$ 408,000.00$
Cat front end Loader 8 month 1 25,500.00$ 204,000.00$
Cat 345 Excavator with Grappler 8 mo.1 25,500.00$ 204,000.00$
Cat 345 Excavator with shear 8 mo.1 25,500.00$ 204,000.00$
Cat 345 Ultra High Demolition with shear/grapple attachment 8 mo.2 49,000.00$ 784,000.00$
Excavator with 15000 lb hammer 8 mo.2 25,500.00$ 408,000.00$
3,133,600.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 2 ea.960 80.00$ 153,600.00$
Laborers 7 ea.960 80.00$ 537,600.00$
Millwrights 3 ea.960 80.00$ 230,400.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Front end Loader with 5 yard bucket 6 mo.1 13,500.00$ 81,000.00$
Cat 345 Excavator with Grappler 6 mo.1 25,500.00$ 153,000.00$
Truck with lowboy 6 wk 1 7,000.00$ 42,000.00$
Excavator with 75,000 lb hammer 6 mo.1 25,500.00$ 153,000.00$
Balloon plugs will be used for insertion into the discharge line as a cement retainer that will then be displaced by concrete or flowable fill to seal below grade.
This task handles the cost for plugging any water intake and discharge lines feeding the plant with process water
Slab removal to be accomplished using hammers and loadout of end dumps for disposal into onsite landfills
Construction debris to be deposited into onsite landfills
All outer structures to be dimantled prior to power block. Assumes all asbestos is abated
As per current operating standards:
Assumed coal will be used to greatest extent possible with 6 inch residual layer that will remain left in placed, covered and vegetated
Assume the Coal pile Area will naturally percolate
Assumes no offsite disposal of coal material
No import of backfill; the tunnels beneath the coal pile will be compromised and backfilled with residual coal or clean material from elsewhere on site
Cut, fill and grade pile to allow for positive runoff
Coal will be depleted to the greatest extent practible
Trucking to transport turbines offsite for sale or recycle.
Hammer will take out turbine pedestals and used for above slab grade, high psi concrete
Assume that the two (2) gantry cranes in turbine will be used to remove turbines and assoicated assets for scraping
The transmission assets are against the turbine bldg. They will be dismantled during utility cut and cap
Crane to used to lower conveyors and appurtenances around new stacks to ground for recycle preparation
Labor QTY UOM HRS RATE SUBTOTAL
Operators 6 ea.216 80.00$ 103,680.00$
Laborers 4 ea.216 80.00$ 69,120.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Front end Loader with 5 yard bucket 1.25 mo.1 25,500.00$ 31,875.00$
Cat 345 Excavator with Grappler 1.25 mo.1 25,500.00$ 31,875.00$
Cat 345 Excavator with shear 1.25 mo.1 25,500.00$ 31,875.00$
Cat 345 Ultra High Demolition with shear/grapple attachment 1.25 mo.1 49,000.00$ 61,250.00$
Excavator with 15,000 lb hammer 1 mo.1 25,500.00$ 25,500.00$
355,175.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 3 ea.640 80.00$ 153,600.00$
Laborers 7 ea.640 80.00$ 358,400.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 950G rubber tire loader with demo Bucket 4 mo.1 13,600.00$ 54,400.00$
Cat 345 Excavator with Grappler 4 mo.1 25,500.00$ 102,000.00$
Cat 345 Excavator with Grappler 4 mo.1 25,500.00$ 102,000.00$
Cat 345 Excavator with Grappler 4 mo.1 25,500.00$ 102,000.00$
Manitowoc 12000 1 ea.160 70.00$ 11,200.00$
ODC QTY UOM HRS RATE SUBTOTAL
Implosion contractor 1 ea.1 115,000.00$ 115,000.00$
998,600.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 3 ea.1760 80.00$ 422,400.00$
Laborers 7 ea.1760 80.00$ 985,600.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 950G rubber tire loader with demo Bucket 11 mo.1 13,600.00$ 149,600.00$
Cat 345 Excavator with Grappler 11 mo.1 25,500.00$ 280,500.00$
Cat 345 Excavator with Shear 11 mo.1 25,500.00$ 280,500.00$
2,118,600.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 1 ea.3200 80.00$ 256,000.00$
Laborers 2 ea.3200 80.00$ 512,000.00$
Equipment QTY UOM HRS RATE SUBTOTAL
Cat 345 Excavator with Grappler 10 mo.1 25,500.00$ 255,000.00$
1,023,000.00$
Labor QTY UOM HRS RATE SUBTOTAL
Project Manager 1 ea.3360 80.00$ 268,800.00$
Site Superintendent 1 ea.3360 75.00$ 252,000.00$
Health and Safety Officer 1 ea.2200 60.00$ 132,000.00$
Project Controls 1 ea.1600 60.00$ 96,000.00$
Project Accountant 1 ea.3360 43.00$ 144,480.00$
Subcontractor Management 1 ea.600 45.00$ 27,000.00$
Mechanic with full service truck 1 ea.2900 125.00$ 362,500.00$
Foremen 2 ea.3360 70.00$ 470,400.00$
Structural Engineer 1 ea.850 100.00$ 85,000.00$
1,838,180.00$
Travel QTY UOM HRS RATE SUBTOTAL
2200 ea.1 145.00$ 319,000.00$
Misc. travel Expenses 15 ea.1 1,500.00$ 22,500.00$
341,500.00$
Dismantle Turbine Generator building 27 days 1.25 months
Prepare Boiler Structures for Implosion, Implode structure Units 1-5 80 days 4 months
Prepare and process steel 220 days11 months
400 days20 monthsLoad and Ship Salvage
420 days21 monthsAdministrative - General Conditions
Task 11
Task 12
Per diems + lodging (JTR @ $145/day ) Rock Springs, WY (5 people. Local labor assumed at no per diem)
Task 8
Task 9
Task 10
Misc. Equipment/Materials QTY UOM HRS RATE SUBTOTAL
Pickup Trucks 21 mo.1 1,650.00$ 34,650.00$
Conex Box 21 mo.1 900.00$ 18,900.00$
50-75 KW Generator 10 mo.1 1,860.00$ 18,600.00$
Manlift (80' boom)21 mo.2 1,358.00$ 57,036.00$
Cutting Torch assembly including gases 21 mo.1 500.00$ 10,500.00$
Small tool Allowance 15 ea.1 1,500.00$ 22,500.00$
End dump - 25 Ton 21 mo.1 7,000.00$ 147,000.00$
Re certify gantry cranes 2 ea.1 5,000.00$ 10,000.00$
Lull forklift 10,000#21 mo.1 7,000.00$ 147,000.00$
BobcatS220 Skidsteer 21 ea.1 3,500.00$ 73,500.00$
Office Trailer plus block, level tie down and stairs 21 mo.1 850.00$ 17,850.00$
Portable Toilets (4)21 mo.4 276.00$ 23,184.00$
Dust Boss 21 mo.1 2,500.00$ 52,500.00$
Project Meetings 15 ea.1 2,500.00$ 37,500.00$
Fit testing, turnover and Medical testing 50 ea.1 400.00$ 20,000.00$
21 mo.2 3,200.00$ 134,400.00$
2 ea.1 10,000.00$ 20,000.00$
845,120.00$
Landfill Disposal Fees QTY UOM HRS RATE SUBTOTALAssorted Construction debris for Offsite Landfill namely C&D debris from Offices and storage buildings. Total square footage is approx 87,000 SF or 90 loads of 90 loads 1 $ 1,100.00 $99,000.00
$99,000.00
Equipment Fuel Oil Gas Materials Allowable QTY UOM HRS RATE SUBTOTAL
Manlift (80' boom)2 ea.3360 5.00$ 33,600.00$
Cat 950G rubber tire loader with demo Bucket 1 ea.3360 30.00$ 100,800.00$
Lull Forklift 1 ea.3360 25.00$ 84,000.00$
Cat 345 Excavator with Grappler/Processor 1 ea.3360 50.00$ 168,000.00$
Cat 345 Excavator with Shear 1 ea.3360 50.00$ 168,000.00$
Cat 345 Excavator with Grappler 2 ea.3360 50.00$ 336,000.00$
Cat 345 UHD (160 days)1 ea.1280 50.00$ 64,000.00$
Cat D-5 Dozer 1 ea.1600 30.00$ 48,000.00$
Water Rucks 2 ea.1600 50.00$ 160,000.00$
Excavator with 75000# Hammer 1 ea.3360 50.00$ 168,000.00$
Manitowoc 12000 crane 1 ea.160 50.00$ 8,000.00$
End dump - 25 ton 4 ea.3360 60.00$ 806,400.00$
50-75 KW Generator 1 ea.1600 10.00$ 16,000.00$
4WD Pickup Trucks 4 ea.3360 3.50$ 47,040.00$
BobcatS220 Skidsteer 2 ea.1600 10.00$ 32,000.00$
Heavy Equipment Repair Contingency of 10% of total cost for tasks 1 -6. This is
an allowance.0.1 ea.1 4,354,300.00$ 435,430.00$
2,675,270.00$
TOTAL PRICE 15,903,525.00$
STD MARKUP OF 8%1,272,282.00$
GRAND TOTAL DEMOLITON 17,175,807.00$
Labor QTY UOM HRS RATE SUBTOTAL
Operators 5 ea.320 80.00$ 128,000.00$
Laborers 6 ea.320 80.00$ 153,600.00$
Equipment
Cat 950G rubber tire loader 2.5 mo.1 13,600.00$ 34,000.00$
Cat 345 Excavator with Grappler 2.5 mo.1 25,500.00$ 63,750.00$
Hydraulic stack muncher 2.5 mo.1 30,000.00$ 75,000.00$
Manitowoc 12000 2.5 mo.1 25,500.00$ 63,750.00$
ODC
Implosion Contractor 1 ea 1 350,000.00$ 350,000.00$
868,100.00$
Labor QTY UOM HRS RATE SUBTOTAL
Project Manager 1 ea.320 80.00$ 25,600.00$
Site Superintendent 1 ea.320 75.00$ 24,000.00$
Health and Safety Officer 1 ea.100 60.00$ 6,000.00$
Project Controls 1 ea.80 60.00$ 4,800.00$
Project Accountant 1 ea.320 43.00$ 13,760.00$
Subcontractor Management 1 ea.40 45.00$ 1,800.00$
Structural Engineer 1 ea.160 100.00$ 16,000.00$
91,960.00$
Travel
250 ea.1 154.00$ 38,500.00$
5 diems
38,500.00$
Misc. Equipment/Materials QTY UOM HRS RATE SUBTOTAL
Pickup Trucks 2.5 mo.1 1,650.00$ 4,125.00$
Conex Box 2.5 mo.1 900.00$ 2,250.00$
Small tool Allowance 10 ea.1 1,500.00$ 15,000.00$
Dust Boss 2.5 mo.1 2,500.00$ 6,250.00$
Fit testing, turnover and Medical testing 15 ea.1 400.00$ 6,000.00$
33,625.00$
Equipment Fuel Oil Gas Materials Allowable QTY UOM HRS RATE SUBTOTAL
Cat 950G rubber tire loader 1 ea.320 30.00$ 9,600.00$
Manitowoc 12000 1 ea.320 70.00$ 22,400.00$
Cat 345 Excavator with Shear 1 ea.320 50.00$ 16,000.00$
Cat 345 Excavator with Grappler 1 ea.320 50.00$ 16,000.00$
64,000.00$
TOTAL PRICE 1,096,185.00$
STD MARKUP OF 8%87,694.80$
GRAND TOTAL STACK DEMOLITON 1,183,879.80$
Processing time included under Phases 1 and 2 tab
Implode all stacks is approximately $200/lf x 1,980 lineal feet = $396,001
Concrete Stacks have three pipes in each
Concrete Stacks 1 and 2 = 550' each
Total lineal footage of stacks 1-4 =
Unit 4 Stack is metal
Stacks Units 1, 2, 3 and 4 = approximately 220' each
Per diems + lodging (JTR @ $154/day ) Casper Wyoming
ID Tas ame ura on ar n s
1 Premobilization Plans and Permitting 22 days Thu 6/1/17 Fri 6/30/17
2 Mobilization Demobilization 15 days Mon 7/3/17 Fri 7/21/17
3 Site Setup/ Utility cut and Cap 60 days Mon 6/26/17 Fri 9/15/17
4 Plug and Grout Water Intake Pipes 15 days Mon 6/26/17 Fri 7/14/17
5 Coal Pile Closure 40 days Mon 9/4/17 Fri 10/27/17
6 Dismantle All Outer Structures,Tanks, Buildings, Scrubbers, Silos, Transmission lines etc
160 days Mon 9/11/1 Fri 4/20/18
7 Dismantle Turbine Generators 120 days Mon 4/23/18 Fri 10/5/18
8 Dismantle Turbine Generator Building 27 days Mon 10/8/18 Tue 11/13/1
9 Prepare boiler Structures for Implosion, Implode Structure Units 1-4 80 days Mon 10/22/18 Fri 2/8/19
10 Prepare and Process Steel 220 days Mon 4/30/18 Fri 3/1/19
11 Load and ship All Salvage 400 days Mon 9/11/1 Fri 3/22/19
12 Dismantle Stacks 2.5 mons Mon 12/3/18 Fri 2/8/19
13 dministrative 472 days?Thu 6/1/17 Fri 3/22/19
June July ugust Septemb October NovembeDecembe January FebruaryMarch pril May June July ugust Septemb October NovembeDecembeJanuary FebruaryMarch
Task
Split
Milestone
Summary
Project Summary
External Tasks
External Milestone
Inactive Task
Inactive Milestone
Inactive Summary
Manual Task
Duration-only
Manual Summary Rollup
Manual Summary
Start-only
Finish-only
Progress
Deadline
Page 1
Project: DRAFT Dave Johnston Plantt Date: Thu 9/4/14
SECTION 1.4 Schedule
2.0 Environmental
The following section presents a summary of environmental considerations and projected costs for the
decommissioning and demolition of the Dave Johnston Generating Station and surrounding grounds in its
entirety. Estimated closure costs are summarized in the table below.
Closure Area Estimated Cost
Total Estimated Environmental Costs $32,864,000
2.1 Asbestos Abatement
Numerous asbestos surveys have been conducted at the generating station and PacifiCorp has been
actively removing asbestos containing materials (ACM). PacifiCorp provided CB&I with its projected
removal cash flows from 2014 through 2026 for removal of ACM of the plant and cooling towers. The
sum of these cash flows were $3,043,799 for the plant and $1,126,000 for the cooling towers. Therefore a
total asbestos abatement expenditure of $4,169,800 has been included in the demolition study.
2.2 Environmental Permits/Plans
A number of environmental permits and plans will be required prior to and during decommissioning and
demolition of the generating station. Two main categories of permits exists: 1) active permits such as
Title V Air Emissions and NPDES water discharge that will need to be cancelled, and 2) demolition
permits/plans that will need to be obtained by the demolition contractor.
CB&I has incorporated an allowance of $75,000 for the cancellation of active permits and obtaining new
demolition permits and plans.
2.3 Hazardous and Universal Waste Disposal
Hazardous materials are located through the main generating station, support facilities and in equipment,
tanks, piping, drums and totes. For the purposes of this study it is assumed that hazardous materials not
stored in containers (tanks, drums and totes) will be used entirely or sent to another plant for use. These
materials are commonly used by the maintenance department and would include commercial-sized
products such as spray paint, solvents, greases, oils, etc…
To determine the cost of hazardous wastes during decommissioning and demolition, CB&I primarily
considered the amount of product stored onsite in storage tanks, totes and drums. Based on the SPCC
plan provided by PacifiCorp, there are 29 aboveground storage tanks (ASTs) storing oil-based products
such as fuel oil, lube oil, diesel fuel, gasoline and used oil with a total capacity of 772,699-gallons. In
addition the plan estimates there are 124 drums (55-gallons each) and 24 totes (330-gallons each) onsite
storing oil-based products. Finally, the SPCC plan lists 55 transformers with a total capacity of 119,426-
gallons storing mineral oil.
No inventories of hazardous and universal wastes were conducted as part of this study so CB&I relied on
the data provided in the SPCC plan and other demolition studies of similar generating stations. Universal
wastes include items such as fluorescent lamps, batteries and mercury containing devices. For disposal of
hazardous wastes not contained in tanks, drums or totes an allowance was estimated.
Item Estimated Cost
Assumptions:
• All tanks, totes, drums and transformers are at 25% of capacity at time decommissioning starts
• Silos storing fly ash and lime will be empty by the start of decommissioning and any remaining
product disposed in landfills and/or ponds
• Used oils, diesel and gasoline can be recycled
• Mineral oils in transformers do not contain PCBs
• Transformers will be drained but not cleaned
• Tank structures and transformers are included in salvage value estimates
2.4 Pond Closure
The Dave Johnson Generating Station has seven ponds that are used for disposal of cooling water,
scrubber effluent, wastewater, stormwater and bottom ash, for example. The table below lists the
estimated surface area of each of the ponds as determined through review of Google Earth maps with
imagery dated October 2013.

Pond Name Capacity (acre feet) (square feet) CCR? Closure Cost
4A Ash Pond 200 750,000 Yes $2,760,000
4B Ash Pond 220 800,000 Yes $3,036,000
No.4 Clear Pond 30 135,000 Yes $414,000
1B Ash Pond 135 525,000 Yes $1,863,000
1A Ash Pond 155 100,000 Yes $2,139,000
1B Clear Pond 25 115,000 Yes $345,000
1A Clear Pond 17 75,000 Yes $234,600
Blowdown Canal 3 30,000 Yes $41,400
Recirculation Canal* 24 235,000 Yes $331,200
Total $11,164,200
* Capacity, surface area and estimated closure cost determined by CB&I using data provided in
the assumptions below
The estimated closure costs provided by PacifiCorp were based on the following assumptions:
• RCRA Subtitle D regulations promulgated 12/19/2014, enforced 6/19/2015,
• Evapotranspiration Dome closure methodology: 1) dewatering, 2) base solidification, 3) fill layer
placement, 4) vegetative layer placement, 5) re-vegetation,
• CCR Pond Closure Cost ($/acre-ft) is $13,800 based on JB FGD Pond 1 actual closure cost, and
• Non-CCR Pond Closure Cost ($/acre-ft) is $11,700 based on TetraTech/S&L estimate

The total cost to close the seven ponds, based on the above assumptions, is estimated to be $11,164,200. 2.5 Landfill Closure
PacifiCorp provided CB&I with an estimated landfill closure cost of $15,500,000. This cost includes
post-closure monitoring. Please note that the landfills around the generating station are closed as the
individual units are filled so final landfill closure costs may vary depending upon the generating station
decommissioning date.
2.6 Remediation of Contaminated Soils and Groundwater
The generating station is currently under a voluntary remediation program (VRP) action with Wyoming
Department of Environmental Quality (WYDEQ) for releases from underground fuel lines. PacifiCorp
provided CB&I with a current estimated cost of $870,000 to complete remediation efforts associated with
the release. Remedial efforts are ongoing so costs are expected to decrease over time.
As the generating station is decommissioned and buildings/structures demolished, it is likely that
additional contamination will be discovered during this process and require remedial actions. Therefore
CB&I has placed an allowance of $250,000 into the closure estimate to cover potential future remediation
costs. The total closure cost for remediation of contaminated soils and groundwater is estimated to be
$1,120,000.

3.0 Salvage
The salvage value associated with the Huntington Station Generating Facility was compiled and estimated
using available drawings of the plant’s structural steel, equipment specifications available at the plant, and
actual measurements taken during the onsite inspection. The team conducted a review of critical
documents provided by PacifiCorp. The team conducted a brief walk-down visually confirming the data
provided in the documents, as well as speaking directly with plant personnel to answer critical questions.
As a result of these valuation methods, the total weights of ferrous metals (steel), non-ferrous metals
(copper and brass), stainless steel, and other alloys have been estimated and are presented below in Table
1. All ferrous and non-ferrous weights are reported in gross tons.

Table 1 – Material Salvage Estimate
Category Steel (gross
tons)
Copper
(gross tons) Steel (gross
tons)
All Structural Steel and Recoverable Rebar 9,319.7
Equipment
Tanks and Ductwork
Facility Totals 23,949.1 1,558.4 974

The salvage summary is presented in Table 2. Based on the remote location of the plant, the scrap that is
recycled will need to be transported to a larger metropolitan area. All material will be required to leave
site by truck, however, transferring to rail car may prove more cost effective depending on the distance to
the recycler. The cost associated with shipping the material to market is included in the demolition cost
analysis. The value of the salvage summary is based on the latest market values as published by the
American Metals Market. A detailed summary is also located in Attachment 2 – Material Salvage
Summary. When a large plant, such as Dave Johnston, is decommissioned, it is ideal to negotiate with
several scrap dealers to determine who will provide the best value for the material. Costs associated with
processing and material sizing as well as transporting should be included in the financial analysis when
selecting a dealer.

Table 2 – Salvage Value Summary
Current Average Salvage Value $285/gross
ton $5,777/ton $1,278/gross ton
Total Salvage Value Subtotal $6,825,502 $9,002,669 $1,245,387
Total Salvage Value $17,073,559
3.1 Materials by Category
3.1.1 Structural Steel and Rebar
There is a considerable amount of structural steel used in the construction of a power plant which includes
I-beams and other structural shapes, as well as tanks, vessels and duct work constructed of plate steel.
Rebar is also a sizable portion of the overall recoverable steel depending on the extent of demolition. The
flue stacks, main and boiler feed pump turbine pedestals, and other concrete silos contain rebar
throughout their structures.
The structural steel and rebar summary for the plant includes:
•the steam turbine building
•the boiler houses
•AQCS areas to include the Units 1/2/3 precipitators, Unit 3/4 SDA’s and baghouses
•coal conveyor and coal yard area
The rebar summary includes:
•flue stacks, lime storage silo and fly ash storage silo
•steam turbine generator pedestals
•foundation rebar
3.1.2 Boiler Material
The boiler steam drums, water walls, economizers and reheat and superheat pendants were included in
this material summary. Boiler area piping to include the boiler drains, downcomers, and headers are also
included in the bulk of boiler material in the ferrous salvage material estimate. All of the boiler material is
assumed to be carbon steel and is reflected in the overall salvage value accordingly. Some alloy rich
sections may have additional value depending on arrangements with the scrap purchaser. Generally scrap
yards follow the line of thought that if a magnet sticks to the material, then it is carbon steel. If a magnet
does not adhere to the material then it is stainless. Clearly marked grades of stainless steel have varying
values, which should be specified with the scrap purchaser.
3.1.3 Heat Exchangers
An array of heat exchangers were identified and incorporated into the overall salvage total. Heat
exchangers, specifically shell and tube style represent a significant amount of weight for both carbon steel
for the shell and stainless steel or brass for the tubes. The heat exchangers are comprised primarily of the
surface condensers, LP and HP feedwater heaters, lube oil coolers, closed cooling water coolers and the
gland steam condenser.

The condensers for each of the steam turbines are surface style condenser consisting of a large “box”
made of carbon steel with an array of tubes in a wet open looped cooling water arrangement with cooling
water being provided from the onsite cooling towers. The tubes in the Units 1 and 2 condensers were
identified as Admiralty brass, which has a copper content of 70 percent, and valued accordingly. The
tubes in the Units 3 and 4 condensers have been identified as a mixture of stainless steel and Admiralty
brass. The ratios on Units 3 and 4 were not provided, so the analysis calculates the tube material as if it
were all stainless steel. The main condenser shell and support materials were included in the ferrous
materials summary and stainless materials summary.

Since the deaerators and respective storage tanks are a direct contact heat exchanger it does not have
copper or stainless steel tubes, which provide additional salvage value as with the feedwater heaters and
the condensers. The weights were calculated from storage tank dimensions and an estimated thickness of
the steel. This value has been included in the ferrous material salvage estimate.

There were other smaller heat exchangers identified on site such as hydrogen coolers, equipment cooling
water and lube oil coolers which are included in the material salvage estimate. Heat exchanger shell
weights are included in the ferrous summary and the tubes are all assumed to be stainless steel, which is
captured in the stainless summary.

3.1.4 Rotating Equipment
The rotating equipment section includes the motor weights as well, so there is both ferrous material and
copper. Rotating equipment for each boiler area includes boiler circulation pumps, forced draft fans,
primary air fans, induced draft fans, coal feeders and coal pulverizers and other equipment that is captured
in the ferrous material estimate. The motors for these pieces of equipment will have additional value due
to the copper windings. The rotor and frame have been included in the ferrous material estimate, and the
windings have been included in the copper material estimate.

The age of the variety of pumps throughout the plant site lend them to have little resale value. This
includes the boiler feed pumps, circulating water pumps, lube oil pumps and other turbine support
systems. As part of the estimate they were included in the ferrous material estimate. The motors for these
pieces of equipment will have additional value due to the copper windings. The rotor and frame have been
included in the ferrous material estimate and the windings have been included in the copper material
estimate.

3.1.5 Turbine/Generator Set
The turbines are reheat style with high-pressure, intermediate pressure and cross-over style low pressure
turbines and exhaust to surface condensers. The design utilizes extraction steam for condensate and feed
water heating. The casings, rotors, steam flow control and turbine stop valves and associated equipment
have been included in the ferrous material salvage estimate. Each primary steam turbine is connected to a
generator. The generators, rotors and stators have been evaluated and divided into ferrous for a portion of
the rotor and casing of the stator and the remaining weight represented in the copper material salvage
estimate.

3.1.6 Cabling
Power plants require a large amount of cabling to power the equipment and provide communication and
indication to the control room. Copper currently has the greatest scrap value of any material on-site, and
its’ removal and reselling should be maximized. It is recommended that the pulling of cable occur early
on in the project to maximize the amount that is recovered. The copper is around 40% more valuable if
the insulation has been removed. Depending on the insulation material, it is encouraged to have a
insulation stripping operation to ensure maximum revenue. Some insulation contains asbestos, which
complicates the removal process.

3.1.7 Piping and Valves
Piping is routed throughout the plant site. The salvage summary includes the major connecting systems
such as condensate, feedwater, main steam and service water. While some of the feedwater and balance of
plant steam piping may be steel alloys, all of the piping was conservatively valued as carbon steel.
Additionally, the piping in condensate systems are often stainless steel, which accounts for additional
value compared to carbon steel.

3.1.8 Transformers
Transformers have the highest potential resale because they are able to be reconditioned and returned to
service. For the purposes of this report, as requested by PacifiCorp, CB&I conservatively estimated the
value of generating station transformers as recycled material. The analysis accounted for transformers
from the GSU into the plant. The large switchyard and its’ assets was assumed to belong to the
transmission company, and therefore not included in this analysis. The primary transformers identified as
part of the decommissioning of the facility are the Generator Step Up (GSU) transformers, the unit
auxiliary transformers, the start-up transformers and AQCS area transformers. The transformer shells and
portions of their cores have been included in the ferrous material estimate. The copper windings in the
transformers have been included in the copper material estimate.

3.1.9 Tanks and Ductwork
Tanks and ductwork represent a significant portion of carbon steel salvage. Examples of tanks include
the elevated water storage tank, condensate and condensate polishing vessels, other water storage tanks,
lube oil reservoirs, compressed air receivers, fuel oil storage tanks, coal silos, scrubber vessels and stack
liners as well as the abandoned steel stacks. The majority of the ductwork is represented in the boiler
area, both up and downstream of the boiler. The interconnections to precipitators, baghouses, scrubbers
and stacks are a significant portion of the salvage estimate.

3.1.10 Spare Parts
Spare parts are not accounted for in this analysis as it is assumed that spares are either returned to
suppliers for a credit or transported to other sites for re-use. Depending on the quantity and type of
spares, there is a possibility of additional revenue that should be looked at when it becomes time for
decommissioning. Additionally shop tools, machine shop tools and other portable equipment such as
welding machines can also be sold. Again, this is a task that should be performed just prior to plant
decommissioning. Other issues to keep in mind are that unlike metal salvage, where revenue is able to be
recognized during the decommissioning and demolition process as the materials are taken to the metal
recycler, parts and equipment resale revenue requires a longer lead time. Direct sales and marketing
activities associated with monetizing spare parts inventory typically will require one to two years to
initiate revenue generation with no certainty for resale. Not all parts generate revenue for the project as
the probability of resale is low.
3.2 Market Analysis of Salvage Prices
A critical component of the valuation assessment of the ACE facility is the determination of commodity
pricing for ferrous and non-ferrous metals to be used in the estimate. As discussed further in this section
development of commodity pricing requires an understanding of local, regional and global conditions.
CB&I developed a current market analysis (August 2014) which shows fluctuation in scrap metal prices
across the United States associated with proximity to steel mills and other metal processing facilities.
According to data gathered from American Metal Market (AMM) publications show the average price for
scrap steel delivered to the mill varied from a low $300.00/gross ton in the San Francisco area to a high of
$367.00/gross ton in Pittsburgh. The price range is shown in Table 3.
Table 3 – August 2014 Scrap Price for Steel Across the United States (per gross ton)
Price/ Gross Ton
Birmingham Chicago Detroit Pittsburgh
$360.00 $363.00 $363.00 $367.00 $358.00
Source: AMM
With the global market for materials some scrap metals are exported to other countries for reprocessing.
The metals are prepared and then sent to the nearest port for shipment overseas. The price paid for scrap
steel to be shipped overseas also varies throughout the country. The average price for scrap steel delivered
to the port was provided by AMM’s August Export Yards Buying Prices data and is shown in Table 5.
Table 4 – August 2014 Export Yard Scrap Steel Prices (per ton)
Steel Scrap
$330.00 $280.00 $328.00 $328.00 $295.00
Source: AMM
To provide some perspective of the annual range of steel pricing, as well as multi-year fluctuations, the
three city composite monthly scrap price for ferrous materials over the last two years is shown in Table 4.
The three cities included in the average are Chicago, Philadelphia and Pittsburgh.
Pricing provided for ferrous materials in this valuation assessment reflects an unprepared condition,
considered conservative for the estimate. Prepared steel, for example heavy melt that was processed on
site into 2’x5’ pieces, would generate a per ton price that is 10-30% higher than unprepared material.
Please note that on-site processing may result in an increase in demolition costs to compensate for
additional equipment and manpower to complete processing tasks.
3.3 Salvage Estimate
Decommissioning Material Salvage Estimate
Client PacifiCorp
Power Plant Dave Johnston Station Power Plant
Address
Carbon Steel
Carbon Steel Weight (Gross Stainless Steel Weight Copper Weight Nickel Weight Alloy Weight
Structural Steel and
Rebar $ 2,656,123.74 9,319.73 $ - $ -
Piping and Supports $ 700,305.53 2,457.21 $ - $ -
Boiler $ 402,348.39 1,411.75 $ - 0.00 $ -
Heat Exchangers $ 572,843.72 2,009.98 $ 1,245,387.53 974.48 $ 549,258.03 95.08
Cabling $ - 0.00 $ - $ 2,201,037.00 381.00
Transformers $ 154,384.50 541.70 $ - $ 2,339,685.00 405.00
Tanks and Duct Work $ 1,512,842.40 5,308.22 $ - 0.00 $ -
Miscellaneous
Equipment $ 826,654.12 2,900.54 $ - 0.00 $ 3,912,689.40 677.29 $ - 0.00
3.4 Analysis of Transportation
ESTIMATE ANALYSIS Scrap Not Sized Trucked to Denver, CO FE Scrap - Steel Mill Sized All Trucked to Pueblo, CO FE Scrap - Steel Mill Sized Railcar to Pueblo, CO PacifiCorp Dave Johnston Plant
Item Description Qty U/M Unit Value Item Value Unit Value Item Value Unit Value Item Value
1.1 Scrap Steel (Units 1234) 23,949 G TON $305.00 $6,201,707.67 $248.00 $8,094,860.54 $315.00 $8,094,860.54
1.2 Trucking Cost (20 Tons Net/Load) 1,197 LOAD ($1,567.50) ($1,877,002) ($1,187.50) ($1,421,971) ($475.00) ($568,788)
1.3
Railcar Cost (90 Tons
Net/load) 266 LOAD $0.00 $0.00 $0.00 $0.00 ($3,460.00) ($920,706)
2.1 Scrap Carbon Steel (Units 1234) 0 G TON $190.00 $0.00 $248.00 $0.00 $248.00 $0.00
2.2 Trucking Cost (20 Tons Net/Load) 0 LOAD $1,567.50 $0.00 ($1,187.50) $0.00 ($190.00) $0.00
2.3 Railcar Cost (90 Tons Net/load) 0 LOAD $0.00 $0.00 $0.00 $0.00 $0.00 $0.00
3.1 Scrap Stainless Steel (Units 1234) 974 R TON $1,178 $1,147,372 $1,278 $1,244772 $1,278 $1,244,772
3.2 Trucking Cost (20 Tons Net/Load) 49 LOAD ($1,567.50) ($76,337) ($1,187.50) ($57,831) ($1,567) ($76,312)
3.3 Railcar Cost (90 Tons Net/load) 11 LOAD $0.00 $0.00 $0.00 $0.00 $0.00 $0.00
4.1 Scrap Copper (Units 1234) 1558 R TON $5,712.00 $505,369.20 $5,712.00 $505,369.20 $5,777.00 $9,000,566
4.2 Trucking Cost (20 Tons Net/Load) 78 LOAD ($1,567.50) ($122,108) ($1,187.50) ($92,506) ($1,567) ($122,069)
4.3 Railcar Cost (90 Tons Net/load) 17 LOAD $0.00 $0.00 $0.00 $0.00 $0.00 $0.00
5.1 Scrap Alloy (Units 1234) 0 R TON $0 0 $235.00 $101,050.00 $235.00 $0.00
5.2 Trucking Cost (20 Tons Net/Load) 0 LOAD 0 $33,701.25 ($1,187.50) ($25,531.25) ($190.00) $0.00
5.3
Railcar Cost (90 Tons
Net/load) 0 LOAD 0 $0.00 $0.00 $0.00 $0.00 $0.00
Total Transportation Cost $1,119,087
4.0 Summary of Costs
The CB&I estimate for the total demolition and reclamation costs of the Dave Johnston Plant to be
$35,215,215. The summary table demonstrates the costs of each component and expected salvage value.
Summary Table Amount
Demolition $18,305,687
Environmental (Asbestos, Ponds, Tanks, et al) $32,864,000
Salvage Value (Income) ($15,954,472)
Total Cost of Demolition $35,215,215

PacifiCorp – Multi-Site
Power Plant Demolition Study

Prepared for:
PacifiCorp Inc.
1407 W. North Temple
Salt Lake City, UT 84116

Prepared by:
CB&I Environmental, Inc.
6380 S. Fiddlers Green Cir, Suite 310
Greenwood Village, CO 80111

Revision F

Issued:
03 Oct 2014

PacifiCorp – Multisite
Power Plant Demolition Study
Rev F – Issued: 03 October 2014

LEGAL NOTICE

This report was prepared by CB&I Environmental Inc. (CB&I) solely for
the benefit of PacifiCorp, Inc. Neither CB&I nor any person acting in their
behalf (a) makes any warranty, expressed or implied, with respect to the
use of any information or methods disclosed in this report; or (b) assumes
any liability with respect to the use of any information or methods
disclosed in this report.

Any recipient of this report, by their acceptance or use of this report,
releases CB&I, from liability from any direct, indirect, consequential or
special loss or damage whether arising in contract, tort (including
negligence) or otherwise.

Any study, report or information furnished hereunder shall not be used or
referred to in connection with offering of securities or other offerings.

The information provided in this report does not constitute an offer to
provide any of the services described herein.
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Table of Contents
LIST OF TABLES ......................................................................................................................................... IV
LIST OF ATTACHMENTS ............................................................................................................................. IV
1.0 PROJECT DESCRIPTION ................................................................................................................... 1
2.0 SITE DESCRIPTION ........................................................................................................................... 1
2.1 Jim Bridger Plant Units 1, 2, 3 and 4 ............................................................................................................ 1
2.2 Dave Johnston Plant Units 1, 2, 3 and 4....................................................................................................... 2
2.3 Currant Creek Plant ...................................................................................................................................... 2
2.4 Huntington Plant Units 1 and 2 ..................................................................................................................... 3
3.0 SITE EVALUATION ........................................................................................................................... 3
3.1 Jim Bridger Plant Units 1, 2, 3 and 4 ............................................................................................................ 3
3.1.1 Long-term Site Basis ............................................................................................................................... 3
3.1.2 Decontamination Basis for the Jim Bridger Plant Units 1, 2, 3 and 4 ...................................................... 4
3.1.3 Decommissioning Basis for the Jim Bridger Plant Units 1, 2, 3 and 4 .................................................... 4
3.1.4 Demolition Basis for the Jim Bridger Plant Units 1, 2, 3 and 4 ............................................................... 8
3.1.5 Remediation Basis for the Jim Bridger Plant Units 1, 2, 3 and 4 ........................................................... 16
3.1.6 Assumptions .......................................................................................................................................... 19
3.2 Dave Johnston Units 1, 2, 3 & 4 ................................................................................................................. 19
3.2.1 Long-term Site Basis for Dave Johnston Plant Units 1, 2, 3 and 4 ........................................................ 19
3.2.2 Decontamination Basis for the Dave Johnston Plant Units 1, 2, 3 and 4 ............................................... 20
3.2.3 Decommissioning Basis for the Dave Johnston Plant ............................................................................ 21
3.2.4 Demolition Basis for Dave Johnston Units 1, 2, 3, &4 .......................................................................... 24
3.2.5 Remediation Basis for the Dave Johnston Plant Units 1, 2, 3, and 4 ..................................................... 32
3.2.6 Assumptions .......................................................................................................................................... 35
3.3 Currant Creek ............................................................................................................................................. 35
3.3.1 Long-term Site Basis for the Currant Creek Plant ................................................................................. 35
3.3.2 Decontamination of the Currant Creek Plant ......................................................................................... 36
3.3.3 Decommissioning Basis for the Currant Creek Plant ............................................................................ 37
3.3.4 Demolition Design Basis for the Currant Creek Plant ........................................................................... 39
3.3.5 Remediation Basis for the Currant Creek Plant ..................................................................................... 48
3.3.6 Assumptions .......................................................................................................................................... 50
3.4 Huntington Plant Units 1 and 2 ................................................................................................................... 50
3.4.1 Long-term Site Basis for the Huntington Plant Units 1 and 2 ............................................................... 50
3.4.3 Decommissioning Basis for the Huntington Plant Units 1&2 ............................................................... 51
3.4.4 Demolition Basis for the Huntington Plant Units 1 & 2 ........................................................................ 54
3.4.5 Remediation Basis for the Huntington Plant Units 1 and 2 ................................................................... 63
3.4.6 Assumptions .......................................................................................................................................... 66

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List of Tables

Table 1 – General Division of Responsibilities - Jim Bridger Plant Units 1, 2, 3, and 4 ..............15
Table 2 – General Division of Responsibilities Dave Johnston Units 1, 2, 3 and 4 ....................31
Table 3 – General Division of Responsibilities Currant Creek Generation Facility .....................46
Table 4 – General Division of Responsibilities Huntington Units 1, and 2 ..................................62

List of Attachments

Attachment 1 – Facility Site Plans .............................................................................................................. 67
Attachment 2 – Permit Data ........................................................................................................................ 68
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1.0 Project Description
For each of the four sites, during Phase I of the work conducted under PacifiCorp
Purchase Order Number 3000100237, CB&I has prepared the Design Basis that will
include; a long-term site basis, a decontamination basis, a decommissioning basis, a
demolition basis, and a remediation basis. The four plants included in this study are:
• Jim Bridger Plant Units 1, 2, 3, and 4;
• Currant Creek Plant;
• Huntington Plant Units 1 and 2; and
• Dave Johnston Plant Units 1, 2, 3 and 4.
The Design Basis for each plant establishes minimum engineering specification
requirements for future development of project technical specification packages, and
provides a baseline for the Phase II engineering cost estimate. This Design Basis
document consists of a description of each project component (i.e. long term condition,
decontamination, decommissioning, demolition, and remediation) and has been
developed as a single document, with sections associated with each plant and the
associated sub-bases identified above.
2.0 Site Description
2.1 Jim Bridger Plant Units 1, 2, 3 and 4
The Jim Bridger Plant has a generating capability of 2,120 Megawatts (MW) of
electricity. Approximately 1,411 MW of this output is owned by PacifiCorp while the
remainder is provided to co-owner Idaho Power. The plant is located on a 1,000 acre
site about 30 miles northeast of Rock Springs, Wyoming and was commissioned in
1974.
The four operating units at Jim Bridger Station burn between 8 to 9 million tons of sub-
bituminous coal per year. About two-thirds of the coal is supplied by the Jim Bridger
mine, which is owned and operated by PacifiCorp. The operation at Jim Bridger mine
produces between 4 to 4.5 million tons of coal per year from the underground operation
and between 1 to 1.5 million tons from the surface operation. The coal is delivered by a
2.4 mile belt conveyor. The remainder of the coal is delivered to the plant via rail from
other Wyoming sites.
The structure contains four 20-story boilers to produce steam that equates to 2,400
pounds of pressure per square (psi) inch at 1000 degrees Fahrenheit (°F).
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The units at Jim Bridger are equipped with electrostatic precipitators to control
particulate emission and wet scrubbers using soda ash waste to control sulfur-dioxide
emissions. Scrubbers at all four units experienced an upgrade in 2007 to effectively
scrub almost 90 percent of sulfur dioxide emissions from the plant stacks.
2.2 Dave Johnston Plant Units 1, 2, 3 and 4
The Dave Johnston Plant has four operating units that generate a total of 762 MW of
electricity. The plant is located on a 2,500 acre site near Glenrock, Wyoming. The plant
was commissioned in 1958.
The Dave Johnston plant burns as much as 4 million tons per year of sub-bituminous
coal that formerly came from the nearby Dave Johnston mine, but that is currently
imported to the plant by rail from other Wyoming area mines. The coal is burned by a
20-story boiler to produce steam that is 2,400 pounds of pressure psi at nearly 1,000 °F.
Cooling water discharge is returned to the Platte River, which runs through the plant site.
Units 1, 2 and 3 are equipped with electrostatic precipitators to control particulate
emissions while the Unit 4 boiler is fitted with a wet venturi scrubber for both particulate
matter and sulfur dioxide. A filter bag-house was installed in Unit 3 in 2010 and has been
planned for installation in Unit 4. Additionally Units 3 and 4 have been fitted with low-
nitrogen oxide burners.
Reclamation efforts accompanying the surface mining operation since 1965 were
ramped up in 1999 and completed in 2005.
2.3 Currant Creek Plant
The Currant Creek Plant is a 550 MW plant located near Mona, Utah and covers a 160-
acre site. The generating facility is comprised of a twin combined-cycle gas turbine and
steam turbine plant that was commissioned in 2005. Questar provides natural gas as
fuel to the plant through a 1,075 psi pressurized pipeline capable of delivering 90,000
million British Thermal Units (BTU) per day to the facility. Heat recovery steam
generators receive 1,125 °F exhaust gas from the turbines and heat water into steam
and pass it through a conventional steam turbine at 1,951 psi. Each heat recovery boiler
has the capability for “duct firing’ burning natural gas to supplement the exhaust gas
energy which produces additional steam to the steam turbine. The exhaust steam is
passed through an air-cooled condenser transforming the steam back into water for
reuse in the heat recovery unit. Thirty large motor driven fans blow air across the
radiator tubes to condense the steam into water. Water for the Currant Creek operation
is delivered from two deep bore wells located outside of Mona, Utah.
The combined-cycle process is credited for increasing efficiency at Currant Creek from
the 36 percent (%) efficiency that conventional gas turbines offer to 55 % efficiency and
thus providing a benefit in reduced emissions due to significantly reduced fuel usage.
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The plant is nearly a zero-emission site because the combined-cycle unit does not use
coal as an expendable fuel source and because the boiler is equipped with nitrogen
oxide emission controls, selective catalytic reduction, and a carbon monoxide catalyzer.
2.4 Huntington Plant Units 1 and 2
The Huntington Plant is comprised of two units located on a 1,000-acre tract located
near Huntington City, Utah. Unit 1 was commissioned in 1974 and Unit 2 was
commissioned in 1977. The combined production of Units 1 and 2 is 895 MW of
electricity. Each of the units is equipped with sulfur dioxide emission controls.
Each year, the Huntington Plant burns three million tons of sub-bituminous coal that is
supplied by a 2.4 mile conveyor from the nearby Deer Creek Mine, which is owned and
operated by PacifiCorp. The boiler at the Huntington Plant is 15 stories tall and
produces steam at 2,400 psi and nearly 1,005 °F.
Most of the water for operation of the plant is drawn from the Huntington River Sufficient
water for plant use is released to the Huntington River from the Electric Lake reservoir
23 miles north of the plant in Huntington Canyon.
3.0 Site Design Basis
3.1 Jim Bridger Plant Units 1, 2, 3 and 4
3.1.1 Long-term Site Basis
Numerous options exist for development of the long-term site basis. Options that
may be available to the Owner include the following:
• Restoration to green-field conditions;
o Back to natural (native conditions)
• Restoration to brown-field conditions;
o Property is prepared for reuse as an industrial facility (as determined by individual state and Federal requirements)
• Development of alternate commercial/industrial use under a lease agreement;
o Retain property as an investment for reuse
• Site divestiture;
o Complete turnover of property to another entity
Until these alternatives can be further explored with the Owner, and for initial
pricing purposes, CB&I assumes that the preferred long-term site basis is
associated with restoration to “brown-field conditions”, generally meaning there
are use or development restrictions on the site, with complete removal of site
structures to top of slab. This post-closure condition will include perimeter control
with remediation efforts completed to remove direct contact exposure pathways
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associated with legacy operations. CB&I also assumes that distribution and
transmission assets will remain operational at the plant. This assumption affects
scope assumptions associated with the development of the decommissioning
basis, the demolition basis, and the remediation basis as well.
3.1.2 Decontamination Basis for the Jim Bridger Plant Units 1, 2, 3 and 4
At the Jim Bridger Plant, activities associated with decommissioning, demolition
preparation, equipment conditioning, and demolition may generate a variety of
solid, universal and hazardous waste materials. The decontamination basis
includes cleanup, removal and disposition of materials that require special
handling or disposal prior to demolition. The decontamination basis describes the
required condition of the power plant with regard to hazardous materials, oils,
fuels, and regulated wastes and materials prior to the start of decommissioning
and the start of demolition. The decontamination basis specifically addresses the
type of hazardous material, as well as the source. The types of hazardous
materials may include lead, asbestos, polychlorinated biphenyls (PCB),
chlorofluorocarbons (CFC), radio isotopes, oils, fuels and miscellaneous
hazardous materials such as mercury, acid, caustic, solvents and other
materials. The sources of PCBs are expected to include, but may not be limited
to, lamp fixtures and ballasts and the sources of CFC are expected to include,
but may not be limited to, air conditioning systems and air conditioning
compressor oils.
The decontamination basis includes consideration of the processes and
procedures for the identification, segregation, stockpiling, containerization of
hazardous materials, waste characterization required for waste classification, and
off-site disposal. Batteries, mercury containing equipment, lamps/bulbs, PCB
contaminated oil, and any other miscellaneous universal wastes requiring
disposal due to demolition will be priced to include, handling, transportation,
labor, and proper disposal.
As required by 40 CFR Part 61 Subpart M, also known as the National Emission
Standard for Hazardous Air Pollutants (NESHAP), asbestos containing materials
that may become damaged or friable during demolition activities must be
removed prior to demolition. The decontamination basis will include the
consideration of asbestos abatement requirements based on materials identified
in the ACM survey provided by PacifiCorp and quantified by CB&I during the site
visit, which will not include asbestos sampling.
3.1.3 Decommissioning Basis for the Jim Bridger Plant Units 1, 2, 3 and 4
For the purposes of this discussion decommissioning is defined as follows:
• Decommissioning – to render a facility safe and environmentally compliant
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(neutral) through equipment/facility de-energization, removal of environmental
liabilities, and perimeter security.
The decommissioning basis is developed based on the selected long-term site
basis and determination of demarcation between decommissioning and utility
terminations prior to demolition.
The decommissioning basis will identify requirements for taking the Jim Bridger
Plant Units 1, 2, 3, and 4 from their current state to a condition where the units
and associated powered equipment have been permanently de-energized and
process related chemicals, fuels, waste and residual materials have been
removed. The decommissioning basis will address utility systems isolation and
relocation, and asset recovery, as well as the de-energization of each unit, i.e.
execution of separation from the transmission yard.
System Layup
Initial system layup for Jim Bridger should represent the final configuration of the
plant. The goal is to eliminate any potential energy source from the facility.
Initial plan would be to put in place fire side, water side, scrubber, electrical, and
fuel Lock Out Tag Out’s (LOTO’s). This would allow a chance to do a stepped
approach to removing energy sources.
Initial system layup should include burning all remaining coal in surge bins and
daily silos. This removes potential hot-spot issues with coal remaining in closed
environments for extended periods.
Depending on time of year, water would need to be drained from all process
equipment. This includes all water cooled bearings, condensation return piping,
service water lines, pumps, un-needed fire water points, potable water piping,
and essentially anything that has freeze protection wrapping.
Electrical is usually the longest lead item for de-energizing a facility. If the entire
facility including switchyards are coming off-line, electrical de-energized can be
completed early. This will probably not be the case and therefore will have to
initially proceed on the stepped down LOTO approach. Once switchyards are
isolated the electrical isolation process can proceed.
Compressed air is an essential tool for an operating plant. The compressed air
lines run throughout the facility and can provide a much needed energy source
during decommissioning. It is proposed that the PacifiCorp decommissioning
contractor eliminate this source early. The reason is two-fold; First it eliminates a
potential energy source and therefore a safety issue. Second it is also an energy
opportunity cost and therefore will cost PacifiCorp money to generate
compressed air. It is suggested the decommissioning contractor supply their
own compressed air locally when needed.
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The layup of Jim Bridger should include removal of coal from belts, water from all
exposed piping and pumps, LOTO electrical, (air gap, if possible, switchyard from
units). The goal is to use the least amount of LOTO’s as possible. This allows
greater freedom of access to the decommissioning contractor.
The last item at Jim Bridger for system layup would be any utility reroutes. If the
entire facility comes offline at the same time utility reroutes may not be needed.
If it is a phased approach, all utility reroutes will be required to be engineered.
This is about a year long process and if multiple owners are involved it can take a
little longer.
Asset Recovery
Asset recovery is the process of assigning values to systems and components
through detailed inventories, prior marketing, and available resources, removing
components and the subsequent sale of those items.
Motors, pumps, electrical gear and machine shop equipment can be used across
many industries and can be recovered for more value than scrap. The asset
recovery phase allows for potential recovery of higher return back to the owner,
as long as the equipment is in proper working order.
Jim Bridger asset recovery phase will be to perform an initial system by system
walk down to get an inventory list. The age of the Jim Bridger plant will
determine viability of asset sales or scrap values.
Asset recovery should start before the units are brought off-line, therefore
allowing the asset recovery contractor time to inventory create marketing
materials and align scrap material vendors. This step allows the greatest
flexibility for return on scrap and sale values.
A possible entire facility sale can be considered, but this option requires
considerable marketing efforts. The marketing effort should be started very early
in the planning stage. Engineering support for the transfer should be negotiated
with a potential buyer early in the process.
Removal of Solid Fuels
Initial removal of fuels depends on PacifiCorp. The final off-line date can best
prepare the Jim Bridger plant for solid fuel removal. CB&I recommends that Jim
Bridger facility coordinate with energy marketing very early in the process to
effectively manage stockpiled coal. The best method of elimination is to burn all
possible coal stockpiles. If a thirty or seven day pile is kept on site, plan on
suppliers (mine mouth) cease deliveries. This allows the coal pile to be at a
minimum and therefore cost of remediation of remaining solid fuel can be
decreased.
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Solid fuels can be removed by trucking or by rail. Since Jim Bridger is connected
to a Union Pacific mainline, rail may be the most cost effective manner to remove
waste coal/solid fuel.
Lime for scrubber operations can be mitigated in much the same manner that
coal is mitigated. Early offline date determination and working with the supplier
will prevent excess on-hand material. All lime should be slaked even if not used
prior to shut down. Lime slurry can be used as a dust suppressant for roads and
should be considered as a disposal method if possible.
Further analysis of existing protocols will need to be verified to determine ratios
of mixtures of remaining environmental scrubber materials to determine best
method of handling and disposal.
Removal and Disposal of Ash
Ash can be handled in several methods and may be considered hazardous in the
near future. The easiest method would be to place ash back in mine if possible.
If this may not be feasible at Jim Bridger, disposition by excavation and rail car
loading is best method. Certified landfills would need to be determined once an
off-line date is proposed. The ash remediation is removal and over excavation.
Removal and disposal will be further defined upon final Jim Bridger site
determination.
Handling of Asbestos Inside Equipment and At Equipment Interfaces
During the decommissioning process, all Asbestos Containing Materials (ACM)
at interface points (gaskets, immediately adjoining piping, etc…) will be mitigated.
The suspected ACM will be treated as ACM and will be handled accordingly.
Initially most ACM at interface points can be mitigated utilizing a glove-bag
method. If PacifiCorp is utilizing an alliance partner during normal operations or
utilizing PacifiCorp personnel to mitigate interface points, it would be
advantageous to continue this procedure during decommissioning.
If no contract exists at time of decommissioning, a suggested path would be to
get a local contractor on board for small scale asbestos remediation. This allows
greater flexibility on schedule and costs.
Closing of Raw Water, Evaporation and Coal Combustion Residuals Ponds
Jim Bridger facility includes two raw water ponds, 8 small ponds, and 2
evaporative ponds. The raw water ponds should remain in place as potential
recreational facilities. This may require utility system redesign for pumps placing
water in ponds.
Evaporation ponds should have a predetermined on-board level and should have
an end date or potential fill date. The evaporation pond if lined may be allowed
to be capped in placed for final disposition and long term monitoring.
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Coal residual ponds will need to be drained and remediated. This design basis
will be further defined upon final disposition of facility. Initial remediation efforts
would be to drain and then over-excavate, replace with clean fill and reseed to
final grade.
All permits for Jim Bridger will be determined upon final site determination. Soil
remediation and reseeding efforts should be done with native grasses require
minimum watering after initial germination period.
3.1.4 Demolition Basis for the Jim Bridger Plant Units 1, 2, 3 and 4
For the purposes of this discussion dismantlement/demolition is defined as follows:
• Dismantlement/Demolition – to remove site infrastructure
including equipment, buildings, storage facilities, etc. Dismantlement
activities focus on revenue generation through initial equipment
liquidation and high value salvage activities, followed by overall facility
structural demolition.
The demolition basis describes the conditions and requirements that must be met
for the safe dismantlement/demolition of the plant, and for the closure and
reclamation of all residual holding ponds including the final long-term and short-
term security measures to be employed at the site upon completion of all
demolition and closure activities. The demolition basis includes a general
description of the activities that the Owner, vendors, and contractors will perform
beginning with the pre-demolition planning activities and throughout the entirety
of the demolition schedule. The demolition basis includes a division of
responsibilities for all activities shown below in Table 1: General Division of
Responsibilities - Jim Bridger Plant Units 1, 2, 3, and 4.
The following specific requirements of the demolition basis are described in the
sections below:
• Demolition Permitting Requirements
• Removal of Solid Fuels
• Removal and Disposal of Ash
• Handling of Asbestos Inside Equipment and At Equipment Interfaces
• Closing of Raw Water, Evaporation, and Coal Combustion Residuals Ponds
• Reclamation of Underground Infrastructures and Removal of Foundations
• Reclamation of the Site and Final Site Grading
• Installation of Permanent Perimeter Control
• Operating Permit Closeout
• Long-term Access Control
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Demolition Permitting Requirements
The demolition basis will include preparation of a matrix of all required permits as
they relate to the demolition of the Jim Bridger Plant to include:
• A list of all required permits necessary for the commencement of demolition activities
• The removal of all solids and liquids required prior to dismantlement
• Federal, State and local agency notifications
• Required submittals for the permit
• Engineering review and approval of the dismantlement approach, means and methods
• Acquisition of the Construction/Demolition Permit
The Permitting matrix will include the following information:
• Jurisdiction/Regulated Activity
• Permit/Approval Required
• Submittal Date
• Review Time Required
• Expected Permit Receipt Date
• Assigned Agency Reviewer
• Status
• Permit Number
• Timing Restrictions
• Operating Permit Closeout Status
• Primary Contact – General
• General Comments
Reclamation of Industrial and Coal Combustion Residuals Landfills
The demolition basis will include the identification and survey of all areas related
to current ash impoundments or landfills. A review of as-built drawings of these
must be reviewed and assessed for final closure criteria development.
Removal of Underground infrastructures and Removal of Foundations.
If required by the selected long-term site basis, the demolition basis will include
identification of all underground infrastructures in the form of piping, raceways,
utilities and foundations on a series of drawings showing all utility terminations
and abandonments. A licensed utility locator service should be used by the
Owner to identify all subsurface items that require dismantlement. Drawings
supplied by the Owner will require review to determine the removal criteria of all
structural foundations and infrastructure slated for final removal post structural
dismantlement. The design basis will include identification of the means and
methods for removal of the underground infrastructures and foundations, as well
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as for the disposition of all process materials, such as concrete. In addition,
consideration will be given to any aspects of material reuse on site, such as the
necessary preparation and use of process backfill materials that can remain as
part of the final reclamation of the site.
Reclamation of the Site and Final Site Grading
The demolition basis will address final dismantlement of the plant to grade and
consideration of preparation of a final site grading plan that identifies all finished
grades after all structural foundations and subsurface infrastructure has been
removed, as well as materials slated for use to accomplish final grades.
Incorporation of the final reclamation of coal pile areas, retention basins, landfill
areas or impoundments must be included as part of the closure of the site.
Installation of Permanent Perimeter Control
The demolition basis will address the final perimeter control recommended for
the site. Perimeter fencing, if the primary means of establishing perimeter
control, must including all specifications of the fencing required for installation
including all gates and appurtenances. Potential sources of perimeter control
devices to be used willl be discussed as part of the demolition basis.
Operating Permit Closeout
The demolition basis will include, as part of the permit matrix, the status of
closure of all operating permits. All existing permits will be listed with their
respective dispositions inclusive of lead times with commentary that provides any
issues and issue resolutions. The matrix should be maintained by PacifiCorp’s
contractors for the duration of the project through the final reclamation phase.
Long-term Access Control
The demolition basis will include consideration of the long-term measures that
will be employed for ensuring adequate access control of the site once the
perimeter control measures have been installed. These measures will include an
inspection and maintenance schedule that will be required once the facility is
finally retired.
3.1.4.1 Demolition Design Process Implementation
Detailed process steps of the Demolition Design are to be followed and
include:
• Assignment of a Project Manager – PacifiCorp Employee or Third
Party
• Early involvement of the Engineering and Construction group
• Determination of demolition scope and building specifications
• Number of Phases involved in the demolition.
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• Type of buildings slated for removal.
• Number of employees, executive management, management
• Creation of an internal project team (incorporates all functions)
• Assignment of Third Party Technical Advisor
• Tendering for demolition firms (at least three)
• Design development and final design approval
• Application for permits from all local government agencies
• Demolition
• Asset Recovery
• Reclamation and Restoration
• Long term site security disposition
3.1.4.2 Demolition Design
This section describes a guideline that, along with PacifiCorp’s Basis of
Demolition Design Specification documents, should be followed during
the demolition design phase and incorporated into the Project Plan to be
prepared by PacifiCorp’s contractor. The demolition design should
include the following elements and considerations:
• Design the means and methods to accomplish the decommissioning
of the plant to include the removal of liquid and solid fuels, fluids, and
gases that are environmentally determined to be hazardous prior to the demolition of the support building and the power block of the plant.
• As part of the overall design plan, civil works related to reclamation activities including assessment of site conditions, anticipated grading and drainage considerations, underground utilities, roads, parking
lots, walkways, signage, fencing, security gates and barriers. Reclamation processes and methods will need to be considered.
• All local regulatory codes and laws shall be followed. All PacifiCorp standards shall be followed as a minimum.
• During the design stage special attention shall be paid to the following:
a. Final approval of all site plans and approvals;
b. Health and Safety including all Lock Out/Tag Out procedures identified along with a procedure that interfaces plant
requirements. All procedures are to be OSHA compliant;
c. Permitting – Application of all applicable permits required to perform the closure of the coal pile areas, retention basins and
impoundments, site decommissioning and demolition including
requirements that address implosive demolition if undertaken;
d. Water – Access to potable and reliable water supply;
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e. Electricity – Access to adequate supply based on the power
required by the facility and design of proper temporary electrical systems (or permanent environmental monitoring
systems if required);
f. Additional utility cut and caps required as part of the dismantlement;
g. Closure and removal (if required) of all subsurface piping and
concrete foundation and footing to a depth of 3 feet below grade;
h. Closure and/or removal of the plant water intake structures;
i. Review of all demolition sequencing by a certified structural engineer licensed in the State of Wyoming;
j. Dangerous Goods Removal, Handling (characterization) and,
Disposal;
k. Final site grading;
l. Final reclamation;
m. Short term and long term site security.
n. The basis for Contractor qualifications.
3.1.4.3 Demolition Sequencing
This section describes the General requirements for the sequencing of
construction activities that will be incorporated as part of the Demolition
Basis.
Pre-Demolition Mobilization Tasks
The demolition basis will include a table showing the general division of
responsibilities assigned between PacifiCorp, the Engineer and the
Contractor. This table should be prepared and finalized by the demolition
contractor and presented in the form of an Organization Chart with tie
lines clearly identifying the hierarchy of reporting inclusive of roles and
responsibilities for the demolition work. The demolition basis will include
the basis and assumptions for the management and handling of all
salvage and recycled materials.
Jim Bridger Plant submittals should encompass the following:
Pre-Demolition Mobilization Submittals:
• Project Plan; including plans and specifications for all aspects of the decontamination, decommissioning, demolition, reclamation, water
management, and assessment and decontamination of the facility
• Site Specific Health and Safety Plan (SSHASP)
• Permitting Matrix and Status
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• Demolition Work Plan
• Permitting Plan
• Salvage Management Plan
• Site Grading and Reclamation Plan
Site Setup
Site setup will be addressed in the demolition basis and will clearly
identify the tasks to be performed in preparation for demolition. Typically
during site setup the demolition contractor should identify in the pre-
mobilization plans all aspects related to the mobilization of manpower,
equipment and materials that will be required as part of the work.
Additionally, tasks related to final preparations prior to the start of
dismantlement must also be considered in the design; examples of these
tasks include utility cuts and capping, de-energizing the station to a “dark”
state condition, identification of all critical lifts and rigging plans submitted
prior to the start of the dismantlement sequenced activities.
The demolition basis will address the steps and requirements for the
removal of all assets prior to dismantlement,. As part of the Demolition
Work Plan or under a separate header, the removal of assets should also
be addressed. The demolition contractor must submit the procedures for
all critical lifts and submit rigging plans priorto the start of the
dismantlement sequenced activities. Supplemental asbestos abatement
must also be part of the dismantlement and addressed as a contingency.
The demolition basis will also address post environmental cleaning of the
structure if necessary, and the requirement for controlling fugitive dust
emissions during dismantlement. As part of the SSHASP prepared by the
demolition contractor, air monitoring for fugitive dust emissions must be
included for the purposes of personal protection of the workers and the
community in accordance to OSHA requirements.
Plant Dismantlement
The demolition basis will address the recommended sequence of
activities to be undertaken by the selected demolition contractor. In
particular, the demolition basis will address the methods for:
Removal of Support Structures and outer buildings such as:
• Emission control structures;
• Coal handling equipment;
• Transformers;
• Electrical Transmission Towers to be removed;
• Utility cut and cap program (plant wide);
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• Water intake System;
• Cooling Towers;
• Pumping Stations;
• Shops and Administrative Office Structures;
• On site Water Treatment;
• Transmission substations
• Fire suppression System;
Removal of Structures Related to the Power Block
• Turbines;
• Turbine Hall;
• Condensers;
• Turbine Pedestals and Gantry Crane;
• Turbine Building Structure;
• Above ground and underground storage tanks
• Boilers;
• Boiler Plant Structure;
• Control Center;
• Stacks
• Removal of Interior Electrical Cabling;
• Removal of the Fire Suppression System.
• Salvage Management and loadout
Reclamation and Closure of the Coal Pile and Ash Basins
• Closure Permitting of basins
• Removal of waste coal product off site
• Backfilling of the Coal Pile footprint
• Final Grading
• Topsoil and Seeding.
The demolition basis will also address the preferred methodology of
dismantlement to be acceptable given the structural makeup of all
aspects of the plant. Dismantlement scenarios may involve a piecemeal
removal of structures, removal of all interior appurtenances followed by a
controlled drop of the structure without explosives, or total implosion
scenario.
The review and approval procedure must be identified as part of the
demolition basis to ensure safe operations during dismantlement activities
regardless of the method of dismantlement chosen by PacifiCorp’s
demolition contractor.
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Structural Implosion
The demolition basis will include the considerations required for the
implosion of the structures. The basis for a controlled dismantlement via
implosion and the requirements thereof should consider:
• The methods for the development of the Implosion model;
• Structural Engineering Assessment of the implosion scenario;
• Health and safety;
• Fugitive dust control and monitoring;
• Explosive charges to be used;
• Community Relations.
Engineering Cost Estimates
The demolition basis will be developed in such a manner to provide a
baseline for the engineering cost estimate and a high-level schedule to be
developed in Phase II of this project
Table 1 – General Division of Responsibilities - Jim Bridger Plant Units 1, 2, 3 and 4
Item Task Comment
1 Support Primary Secondary
2 Secondary Primary (I)
3 Removal of Solid Fuels Secondary Primary
4 Secondary Primary
6 Support Primary (I)
7 Combust residual Support Primary (D)
Secondary (O) Primary (I)
9 Support
10 Finished Site Grade Support
11 Support Secondary Primary (I)
12 Secondary Primary (D, I)
13 Secondary Primary (D,I)
14 Secondary Primary
15 Secondary Primary
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Item Task Comment
Selection
16 Primary (I)
17 Demolition Submittals Secondary (R,A) Primary (I)
18 Construction Sequencing Primary (I)
20 Secondary Secondary Primary
Approval (A)

3.1.5 Remediation Basis for the Jim Bridger Plant Units 1, 2, 3 and 4
For the purposes of this study of the Jim Bridger Plant, the word “remediation”
refers to the reclamation of the property to the desired end-use and/or the
reversal or stopping of damage to the environment. The following remediation
basis outlines: the general approach to determining remediation needs to
address soil, surface water, and groundwater impacts; the anticipated
remediation/reclamation efforts to be performed after demolition completion;
describes the required condition of the power plant to provide the proper site
controls to facilitate the long-term site basis, and includes the site monitoring and
access controls needed during remediation activities.
Environmental Permit Closure
An initial step in determining the anticipated closure/remediation needs for the
site includes compiling a detailed summary of the existing environmental permits.
As part of the Phase II decommissioning study site inspections, the existing
environmental permits for the plant will be reviewed to determine the permit
closure requirements for engineering cost estimate evaluation.
Establishment of Remediation Cleanup Goals
Based on the assumption that the selected long-term site basis will be restoration
to “brownfield conditions”, it is assumed for the purpose of this study that the
remediation cleanup target goals will be based on an industrial exposure/re-use
scenario. Following the final decision to decommission the plant, it is
recommended that the site be evaluated to determine the best regulatory option
to guide the closure. There are two primary regulatory options to evaluate with
the Wyoming Department of Environmental Quality (WDEQ): 1. Closure of the
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site through the use of existing permits, permit modifications, or new permit
applications; or 2. Enter the WDEQ Voluntary Remediation Program (VRP). A
pre-application meeting should be requested with the WDEQ to discuss the
appropriateness of the VRP to meet the site closure goals.
For the purpose of this study, it is assumed that the VRP is the best option. The
final VRP agreement will clearly define remediation cleanup goals, engineering
controls, institutional controls, and post-closure care requirements, as applicable.
The engineering cost estimate evaluation will include estimated costs for the
development of the VRP application, application fees, and payment of WDEQ
department costs for the department’s oversight of the voluntary remediation.
Environmental Assessment Needs
Following the completion of a VRP application and approval of eligibility by
WDEQ, a site characterization is required that includes the following:
• Data and information gathering;
• Development of a Site Conceptual Model; and
• Preparation of a Site Characterization Work Plan that meets the performance criteria outlined by the VRP.
The performance criteria include:
• site setting,
• known and potential sources of contamination,
• nature and distribution of contaminants and media properties,
• and human and ecological receptors.
To support environmental needs assessment, a Limited Phase I Environmental
Site Assessment should be completed, prior to plant decommissioning, that
evaluates recognized environmental conditions for all major site features (e.g.,
settling ponds, scrubber ponds, storm water ponds, etc.) and all of the storage
tanks identified in the plant’s Spill Prevention Control and Countermeasures
(SPCC) Plan.
For the pending engineering cost estimate evaluation (Phase II), no
environmental assessment activities are needed at this time. The engineering
cost estimate evaluation will include line item environmental assessment costs
based on PacifiCorp provided information regarding any documented releases
and professional experience from site assessments of similar scale.
Completed, On-going or Pending Remediation Projects
Information has been requested, but only partially provided, regarding any
completed, on-going, or pending remediation projects at the plant. This
information, along with a summary of any existing RCRA Solid Waste
Management Units (SWMUs), will be needed to support the engineering cost
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estimate evaluation. Additionally, any previously completed remediation
evaluations or budgetary cost estimates should be provided for reference. Based
on the preliminary information, there are on-going remediation projects at the
facility including the closure of Flue Gas Desulfurization (FGD) Pond #1 and an
ongoing recovery project from a large oil release.
Anticipated Remediation Projects
The following is a list of anticipated remediation projects that will be included as
line items in the engineering cost estimate evaluation:
• Completion of the on-going closure and remediation of FGD Pond #1 per
permit requirements
• Closure and remediation of FGD Pond #2 under the permit prescribed
closure
• Closure and reclamation of all evaporation ponds
• Closure and reclamation of the Jim Bridger Power Plant Industrial Landfill per the operating permit closure requirements (WDEQ SHWD File #20.455)
• Continue the long-term monitoring programs for all site areas with on-going groundwater monitoring programs
• Continue the on-going remediation project addressing the large oil release (diesel fuel seep) including maintenance of the active construction permit and
continued annual reporting efforts
• Removal and reclamation of the railroad spurs located within the site
boundaries
• Closure of the fly ash storage area
• Closure of the Main Fuel Oil Storage Tank #1 (1,380,000 gallons), the underground fuel oil pipeline, and Fuel Oil Storage Tank #2 (350,000 gallons)
• Closure of all four ash farm units
• Closure of the heavy equipment maintenance shop area
• Closure of the hazardous waste storage room area
• Closure of Lube Oil Tanks #3 and #4
• Closure of the C.W. Chemical Treatment Plant
• Closure of the Above Ground Storage Tank Vehicle Refueling Station (two 4,000-gallon unleaded tanks and one 8,000-gallon diesel tank)
• Closure of the three cooling tower transformer areas
• Closure of the radial stacker coal storage pile area
Potential Cost Savings
The active Jim Bridger Power Plant Industrial Waste Landfill can accept plant
generated wastes including paper products, plastic and metal drums, dirt, wood
products, lunch room wastes, scrap metal, drained filters, and digested domestic
wastewater treatment plant sludge. The current available storage capacity
should be evaluated so the landfill can be utilized to reduce disposal costs during
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the decommissioning/demolition activities. The current Industrial Waste landfill
permit may require a permit modification to cover the acceptance of some of
decommissioning/demolition wastes.
The development of a site-wide final grading plan is recommended. The final
grading plan would evaluate cut-and-fill opportunities on the property to provide
soil cover materials to reduce the material costs for the cap-and-closure of the
existing landfills and closure of existing ponds.
Site Controls
The site will be remediated to VRP determined industrial cleanup standards
which will be protective for an industrial use exposure scenario. Site controls will
be developed on an as needed basis following soil sampling in potential
impacted areas. The foundation slabs will be left in place, providing an
engineered control to limit exposure. Final site grading will be designed to
mitigate erosion issues and reduce long-term maintenance costs. Long-term
monitoring and maintenance of the capped landfills will be estimated. Existing
site controls, such as security fencing, will be left in place and maintenance costs
estimated.
Site Monitoring and Access Controls
Site monitoring needs are unknown at this time and will be based on the
requirements of completed remediation projects. Access control during
remediation activities and post-closure monitoring will be included as a line item
cost.
3.1.6 Assumptions
(Reserved Pending Client Discussion)
3.2 Dave Johnston Units 1, 2, 3 & 4 Design Basis
3.2.1 Long-term Site Basis for Dave Johnston Plant Units 1, 2, 3 and 4
Numerous options exist for development of the long-term site basis. Options that
may be available to the Owner include the following:
• Restoration to green-field conditions;
o Back to natural (native conditions)
• Restoration to brown-field conditions;
o Property is prepared for reuse as an industrial facility (as determined by individual state and Federal requirements)
• Development of alternate commercial/industrial use under a lease
agreement;
o Retain property as an investment for reuse
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• Site divestiture;
o Complete turnover of property to another entity

Until these alternatives can be further explored with the Owner, and for initial
pricing purposes, CB&I assumes that the preferred long-term site basis is
associated with restoration to “brown-field conditions”, generally meaning there
are use or development restrictions on the site, with complete removal of site
structures to top of slab. This post-closure condition will include perimeter control
with remediation efforts completed to remove direct contact exposure pathways
associated with legacy operations. CB&I also assumes that distribution and
transmission assets will remain operational at the plant. This assumption affects
scope assumptions associated with the development of the decommissioning
basis, the demolition basis, and the remediation basis as well.
3.2.2 Decontamination Basis for the Dave Johnston Plant Units 1, 2, 3 and 4
At the Dave Johnston Plant, activities associated with decommissioning,
demolition preparation, equipment conditioning, and demolition may generate a
variety of solid, universal and hazardous waste materials. The decontamination
basis includes cleanup, removal and disposition of materials that require special
handling or disposal prior to demolition. The decontamination basis describes the
required condition of the power plant with regard to hazardous materials, oils,
fuels, and regulated wastes and materials prior to the start of decommissioning
and the start of demolition. The decontamination basis specifically addresses the
type of hazardous material, as well as the source. The types of hazardous
materials may include lead, asbestos, polychlorinated biphenyls (PCB),
chlorofluorocarbons (CFC), radio isotopes, oils, fuels and miscellaneous
hazardous materials such as mercury, acid, caustic, solvents and other
materials. The sources of PCBs are expected to include, but may not be limited
to, lamp fixtures and ballasts and the sources of CFC are expected to include,
but may not be limited to, air conditioning systems and air conditioning
compressor oils.
The decontamination basis includes consideration of the processes and
procedures for the identification, segregation, stockpiling, containerization of
hazardous materials, waste characterization required for waste classification, and
off-site disposal. Batteries, mercury containing equipment, lamps/bulbs, PCB
contaminated oil, and any other miscellaneous universal wastes requiring
disposal due to demolition will be priced to include, handling, transportation,
labor, and proper disposal.
As required by 40 CFR Part 61 Subpart M, also known as the National Emission
Standard for Hazardous Air Pollutants (NESHAP), asbestos containing materials
that may become damaged or friable during demolition activities must be
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removed prior to demolition. The decontamination basis will include the
consideration of asbestos abatement requirements based on materials identified
in the ACM survey provided by PacifiCorp and quantified by CB&I during the site
visit, which will not include asbestos sampling.
3.2.3 Decommissioning Basis for the Dave Johnston Plant
For the purposes of this discussion decommissioning is defined as follows:
• Decommissioning – to render a facility safe and environmentally
compliant (neutral) through equipment/facility de-energization, removal of
environmental liabilities, and perimeter security.
The decommissioning basis is developed based on the selected long-term site
basis and determination of demarcation between decommissioning and utility
terminations prior to demolition.
The decommissioning basis will identify requirements for taking the Dave
Johnston Plant from their current state to a condition where the units and
associated powered equipment have been permanently de-energized and
process related chemicals, fuels, waste and residual materials have been
removed. The decommissioning basis will address utility systems isolation and
relocation, and asset recovery, as well as the de-energization of each unit, i.e.
execution of separation from the transmission yard.
System Layup
Initial system layup for Dave Johnston Plant should represent the final
configuration of the plant. The goal is to eliminate any potential energy source
from the facility. Initial plan would be to put in place fire side, water side,
scrubber, electrical, and fuel Lock Out Tag Out’s (LOTO’s). This would allow a
chance to do a stepped approach to removing energy sources.
Initial system layup should include burning all remaining coal in surge bins and
daily silos. This removes potential hot-spot issues with coal remaining in closed
environments for extended periods.
Depending on time of year, water would need to be drained from all process
equipment. This includes all water cooled bearings, condensation return piping,
service water lines, pumps, un-needed fire water points, potable water piping,
and essentially anything that has freeze protection wrapping.
Electrical is usually the longest lead item for de-energizing a facility. If the entire
facility including switchyards are coming off-line, electrical de-energized can be
completed early. This will probably not be the case and therefore will have to
initially proceed on the stepped down LOTO approach. Once switchyards are
isolated the electrical isolation process can proceed.
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Compressed air is an essential tool for an operating plant. The compressed air
lines run throughout the facility and can provide a much needed energy source
during decommissioning. It is proposed that the PacifiCorp decommissioning
contractor eliminate this source early. The reason is two-fold; First it eliminates a
potential energy source and therefore a safety issue. Second it is also an energy
opportunity cost and therefore will cost PacifiCorp money to generate
compressed air. It is suggested the decommissioning contractor supply their
own compressed air locally when needed.
The layup of Dave Johnston Plant should include removal of coal from belts,
water from all exposed piping and pumps, LOTO electrical, (air gap, if possible,
switchyard from units). The goal is to use the least amount of LOTO’s as
possible. This allows greater freedom of access to the decommissioning
contractor.
The last item at Dave Johnston Plant for system layup would be any utility
reroutes. If the entire facility comes offline at the same time utility reroutes may
not be needed. If it is a phased approach, all utility reroutes will be required to be
engineered. This is about a year long process and if multiple owners are
involved it can take a little longer.
Asset Recovery
Asset recovery is the process of assigning values to systems and components
through detailed inventories, prior marketing, and available resources, removing
components and the subsequent sale of those items.
Motors, pumps, electrical gear and machine shop equipment can be used across
many industries and can be recovered for more value than scrap. The asset
recovery phase allows for potential recovery of higher return back to the owner,
as long as the equipment is in proper working order.
Dave Johnston Plant asset recovery phase will be to perform an initial system by
system walk down to get an inventory list. The age of the Dave Johnston plant
will determine viability of asset sales or scrap values.
Asset recovery should start before the units are brought off-line, therefore
allowing the asset recovery contractor time to inventory create marketing
materials and align scrap material vendors. This step allows the greatest
flexibility for return on scrap and sale values.
A possible entire facility sale can be considered, but this option requires
considerable marketing efforts. The marketing effort should be started very early
in the planning stage. Engineering support for the transfer should be negotiated
with a potential buyer early in the process.
Removal of Solid Fuels
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Initial removal of fuels depends on PacifiCorp. The final off-line date can best
prepare the Dave Johnston Plant for solid fuel removal. CB&I recommends that
Dave Johnston Plant coordinate with PacifiCorp energy marketing very early in
the process to effectively manage stockpiled coal. The best method of
elimination is to burn all possible coal stockpiles. If a thirty or seven day pile is
kept on site, plan on suppliers (mine mouth) cease deliveries. This allows the
coal pile to be at a minimum and therefore cost of remediation of remaining solid
fuel can be decreased.
Solid fuels can be removed by trucking or by rail. Since Dave Johnston Plant is
connected to a Burlington Northern and Santa Fe (BNSF) mainline, rail may be
the most cost effective manner to remove waste coal/solid fuel.
Lime for scrubber operations can be mitigated in much the same manner that
coal is mitigated. Early offline date determination and working with the supplier
will prevent excess on-hand material. All lime should be slaked even if not used
prior to shut down. Lime slurry can be used as a dust suppressant for roads and
should be considered as a disposal method if possible.
Further analysis of existing protocols will need to be verified to determine ratios
of mixtures of remaining environmental scrubber materials to determine best
method of handling and disposal.
Removal and Disposal of Ash
Ash can be handled in several methods and may be considered hazardous in the
near future. At Dave Johnston Plant, disposition by excavation and rail car
loading is probably best method. Certified landfills would need to be determined
once an off-line date is proposed. The ash remediation is removal and over
excavation.
Removal and disposal will be further defined upon final Jim Bridger site
determination.
Handling of Asbestos Inside Equipment and At Equipment Interfaces
During the decommissioning process, all Asbestos Containing Materials (ACM)
at interface points (gaskets, immediately adjoining piping, etc…) will be mitigated.
The suspected ACM will be treated as ACM and will be handled accordingly.
Initially most ACM at interface points can be mitigated utilizing a glove-bag
method. If PacifiCorp is utilizing an alliance partner during normal operations or
utilizing PacifiCorp personnel to mitigate interface points, it would be
advantageous to continue this procedure during decommissioning.
If no contract exists at time of decommissioning, a suggested path would be to
get a local contractor on board for small scale asbestos remediation. This allows
greater flexibility on schedule and costs.
Closing of Raw Water, Evaporation and Coal Combustion Residuals Ponds
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Dave Johnston Plant facility includes a main intake canal, dam, 4 ponds, and 2
small ponds and 1 evaporative pond. The raw water ponds should be drained
and clean fill placed to final grade. The water canal can be coffer dammed to
eliminate water infiltration then filled to final grade.
The dam directly adjacent to the facility would require determination if it is to
remain in place or be removed. At this time no further guidance will be provided
until the disposition is determined.
Evaporation ponds should have a predetermined on-board level and should have
an end date or potential fill date. The evaporation pond if lined may be allowed
to be capped in placed for final disposition and long term monitoring.
Coal residual ponds will need to be drained and remediated. This design basis
will be further defined upon final disposition of facility. Initial remediation efforts
would be to drain and then over-excavate, replace with clean fill and reseed to
final grade.
All permits for Dave Johnston Plant will be determined upon final site
determination. Soil remediation and reseeding efforts should be done with native
grasses require minimum watering after initial germination period.

3.2.4 Demolition Basis for Dave Johnston Units 1, 2, 3, &4
For the purposes of this discussion dismantlement/demolition is defined as follows:
• Dismantlement/Demolition – to remove site infrastructure including
equipment, buildings, storage facilities, etc. Dismantlement activities focus on
revenue generation through initial equipment liquidation and high value
salvage activities, followed by overall facility structural demolition.
The demolition basis describes the conditions and requirements that must be met
for the safe dismantlement/demolition of the plant, and for the closure and
reclamation of all residual holding ponds including the final long-term and short-
term security measures to be employed at the site upon completion of all
demolition and closure activities. The demolition basis includes a general
description of the activities that the Owner, vendors, and contractors will perform
beginning with the pre-demolition planning activities and throughout the entirety
of the demolition schedule. The demolition basis includes a division of
responsibilities for all activities shown below in Table 2: General Division of
Responsibilities – Dave Johnston Plant Units 1, 2, 3 and 4.
The following specific requirements of the demolition basis are described in the
sections below:
• Demolition Permitting Requirements
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• Removal of Solid Fuels
• Removal and Disposal of Ash
• Handling of Asbestos Inside Equipment and At Equipment Interfaces
• Closing of Raw Water, Evaporation, and Coal Combustion Residuals Ponds
• Reclamation of Underground Infrastructures and Removal of Foundations
• Reclamation of the Site and Final Site Grading
• Installation of Permanent Perimeter Control
• Operating Permit Closeout
• Long-term Access Control
Demolition Permitting Requirements:
The demolition basis will include preparation ofa matrix of all required permits as
they relate to the demolition of the Dave Johnston Facility to include:
• A list of all required permits necessary for the commencement of demolition
activities
• The removal of all solids and liquids required prior to dismantlement
• Federal, State and local agency notifications
• Required submittals for the permit
• Engineering review and approval of the dismantlement approach, means and
methods
• Acquisition of the Construction/Demolition Permit
The Permitting matrix will include the following information
• Jurisdiction/Regulated Activity
• Permit/Approval Required
• Submittal Date
• Review Time Required
• Expected Permit Receipt Date
• Assigned Agency Reviewer
• Status
• Permit Number
• Timing Restrictions
• Operating Permit Closeout Status
• Primary Contact – General
• General Comments
Reclamation of Industrial and Coal Combustion Residuals Landfills
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The demolition basis will include the identification and survey of all areas related
to current ash impoundments or landfills. A review of as-built drawings of these
must be reviewed and assessed for final closure criteria development.
Removal of Underground infrastructures and Removal of Foundations.
If required by the selected long-term site basis, the demolition basis will include
identification of all underground infrastructures in the form of piping, raceways,
utilities and foundations on a series of drawings showing all utility terminations
and abandonments. A licensed utility locator service should be used by the
Owner to identify all subsurface items that require dismantlement. Drawings
supplied by the Owner will require review to determine the removal criteria of all
structural foundations and infrastructure slated for final removal post structural
dismantlement. The design basis will include identification of the means and
methods for removal of the underground infrastructures and foundations, as well
as for the disposition of all process materials, such as concrete. In addition,
consideration will be given to any aspects of material reuse on site, such as the
necessary preparation and use of process backfill materials that can remain as
part of the final reclamation of the site.
Reclamation of the Site and Final Site Grading
The demolition basis will address final dismantlement of the plant to grade and
consideration of preparation of a final site grading plan that identifies all finished
grades after all structural foundations and subsurface infrastructure has been
removed, as well as materials slated for use to accomplish final grades. The
Dave Johnston mine has been reclaimed and is not part of the design basis for
this plant site.
Installation of Permanent Perimeter Control
The demolition basis will address the final perimeter control recommended for
the site. If the primary means of establishing perimeter control, perimeter fencing
plan must including all specifications of the fencing required for installation
including all gates and appurtenances. Potential sources of perimeter control
devices to be used will be discussed as part of the demolition basis.
Operating Permit Closeout
The demolition basis will include as part of the permit matrix, the status of closure
of all operating permits. All existing permits will be listed with their respective
dispositions inclusive of lead times with commentary that provides any issues
and issue resolutions. The matrix should be maintained by PacifiCorp’s
contractors for the duration of the project through the final reclamation phase.
Long-term Access Control
The demolition basis will include consideration of the long-term measures that
will be employed for ensuring adequate access control of the site once the
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perimeter control measures have been installed. These measures will include an
inspection and maintenance schedule that will be required once the facility is
finally retired.
3.2.4.1 Demolition Design Process Implementation
Detailed process steps of the Design are to be followed and include:
• Assignment of a Project Manager – PacifiCorp Employee or Third Party
• Early involvement of the Engineering and Construction group
• Determination of demolition scope and building specifications
• Number of Phases involved in the demolition.
• Type of buildings slated for removal.
• Number of employees, executive management, management
• Creation of an internal project team (incorporates all functions)
• Assignment of Third Party Technical Advisor
• Tendering for demolition firms (at least three)
• Design development and final design approval
• Application for permits from all local government agencies
• Demolition
• Asset Recovery
• Reclamation and Restoration
• Long term site security disposition
3.2.4.2 Demolition Design
This section describes a guideline that, along with PacifiCorp’s Basis of
Demolition Design Specification documents, should be followed during
the demolition design phase and incorporated into the Project Plan to be
prepared by PacifiCorp’s contractor. The demolition design should
include the following elements and considerations:
• Design the means and methods to accomplish the decommissioning
of the plant to include the removal of liquid and solid fuels, fluids, and
gases that are environmentally determined to be hazardous prior to the demolition of the support building and the power block of the plant.
• As part of the overall design plan, civil works related to reclamation activities including assessment of site conditions, anticipated grading
and drainage considerations, underground utilities, roads, parking
lots, walkways, signage, fencing, security gates and barriers. Reclamation processes and methods will need to be considered.
• All local regulatory codes and laws shall be followed. All PacifiCorp standards shall be followed as a minimum.
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• During the design stage special attention shall be paid to the following:
a. Final approval of all site plans and approvals;
b. Health and Safety including all Lock Out/Tag Out procedures identified along with a procedure that interfaces plant
requirements. All procedures are to be OSHA compliant;
c. Permitting – Application of all applicable permits required to perform the closure of the coal pile areas, retention basins and impoundments, site decommissioning and demolition including
requirements that address implosive demolition if undertaken;
d. Water – Access to potable and reliable water supply;
e. Electricity – Access to adequate supply based on the power
required by the facility and design of proper temporary electrical systems; (or permanent environmental monitoring
systems if required).
f. Additional utility cut and caps required as part of the dismantlement;
g. Closure and removal (if required) of all subsurface piping and
concrete foundation and footing to a depth of 3 feet below grade;
h. Closure and/or removal of the plant water intake structures;
i. Review of all demolition sequencing by a certified structural engineer licensed in the State of Wyoming;
j. Dangerous Goods Removal, Handling (characterization) and, Disposal;
k. Final site grading;
l. Final reclamation;
m. Short term and long term site security.
n. The basis for Contractor qualifications.
3.2.4.3 Demolition Sequencing
This section describes the General requirements for the sequencing of
construction activities that will be incorporated as part of the Demolition
Basis.
Pre-Demolition Mobilization Tasks
The demolition basis will include a table showing the general division of
responsibilities assigned between PacifiCorp, the Engineer and the
Contractor. This table should be prepared and finalized by the demolition
contractor and presented in the form of an Organization Chart with tie
lines clearly identifying the hierarchy of reporting inclusive of roles and
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responsibilities for the demolition work. The demolition basis will include
the basis and assumptions for the management and handling of all
salvage and recycled materials.
The demolition basis will address the required submittals for the work at
Dave Johnston Plant. The submittals should encompass the following:
Pre-Demolition Mobilization Submittals:
• Project Plan; including plans and specifications for all aspects of the
decontamination, decommissioning, demolition, reclamation, water management, and assessment and decontamination of the facility
• Site Specific Health and Safety Plan (SSHASP)
• Permitting Matrix and Status
• Demolition Work Plan
• Permitting Plan
• Salvage Management Plan
• Site Grading and Reclamation Plan
Site Setup
Site setup will be addressed in the demolition basis and will clearly
identify the tasks to be performed in preparation for demolition. Typically
during site setup the demolition contractor should identify in the pre-
mobilization plans all aspects related to the mobilization of manpower,
equipment and materials that will be required as part of the work.
Additionally, tasks related to final preparations prior to the start of
dismantlement must also be considered in the design; examples of these
tasks include utility cuts and capping, de-energizing the station to a “dark”
state condition, identification of all critical lifts and rigging plans submitted
prior to the start of the dismantlement sequenced activities.
The demolition basis will address the steps and requirements for the
removal of all assets prior to dismantlement,. As part of the Demolition
Work Plan or under a separate header, the removal of assets should also
be addressed. The demolition contractor must submit the procedures for
all critical lifts and submit rigging plans priorto the start of the
dismantlement sequenced activities. Supplemental asbestos abatement
must also be part of the dismantlement and addressed as a contingency.
The demolition basis will also address post environmental cleaning of the
structure if necessary, and the requirement for controlling fugitive dust
emissions during dismantlement. As part of the SSHASP prepared by the
demolition contractor, air monitoring for fugitive dust emissions must be
included for the purposes of personal protection of the workers and the
community in accordance to OSHA requirements.
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Plant Dismantlement
The demolition basis will address the recommended sequence of
activities to be undertaken by the selected demolition contractor. In
particular, the demolition basis will address the methodology for:
Removal of Support Structures and outer buildings such as:
• Emission control structures;
• Coal handling equipment;
• Transformers;
• Electrical Transmission Towers to be removed;
• Utility cut and cap program (plant wide);
• Water intake System;
• Cooling Towers;
• Pumping Stations;
• Shops and Administrative Office Structures;
• On site Water Treatment;
• Transmission substations
• Fire suppression System;
Removal of Structures related to the Power Block
• Turbines;
• Turbine Hall;
• Condensers;
• Turbine Pedestals and Gantry Crane;
• Turbine Building Structure;
• Above ground and underground storage tanks
• Boilers;
• Boiler Plant Structure;
• Control Center;
• Stacks
• Removal of Interior Electrical Cabling;
• Removal of the Fire Suppression System.
• Salvage Management and loadout
Reclamation and Closure of the Coal Pile and Ash Basins
• Closure Permitting of basins
• Removal of waste coal product off site
• Backfilling of the Coal Pile footprint
• Final Grading
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• Topsoil and Seeding.
The demolition basis will also address the preferred methodology of
dismantlement to be acceptable given the structural makeup of all
aspects of the plant. Dismantlement scenarios may involve a piecemeal
removal of structures, removal of all interior appurtenances followed by a
controlled drop of the structure without explosives, or total implosion
scenario.
The review and approval procedure must be identified as part of the
demolition basis to ensure safe operations during dismantlement activities
regardless of the method of dismantlement chosen by PacifiCorp’s
demolition contractor.
Structural Implosion
The demolition basis will include the considerations required for the
implosion of the structures. The basis for a controlled dismantlement via
implosion and the requirements thereof should consider:
• The methodology for the development of the Implosion model;
• Structural Engineering Assessment of the implosion scenario;
• Health and safety;
• Fugitive dust control and monitoring;
• Explosive charges to be used;
• Community Relations.

Engineering Cost Estimates
The demolition basis will be developed in such a manner to provide a
baseline for the engineering cost estimate and a high-level schedule to be
developed in Phase II of this project
Table 2 – General Division of Responsibilities Dave Johnston Plant Units 1, 2, 3 and 4
Item Task Comment
1 Support Primary Secondary
2 Primary (I)
3 Removal of Solid Fuels Secondary Primary
4 Secondary Primary
6 Support Primary I)
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Item Task Comment
9 Site Reclamation Support
10 Finished Site Grade Support
11 Support Secondary Primary (I)
12 Secondary Primary (D, I)
13 Secondary Primary (D,I)
14 Secondary Primary
15 Abatement Contractor Secondary Primary
16 Primary (I)
17 Demolition Submittals Secondary (R,A) Primary (I)
18 Construction Sequencing Primary (I)
20 Secondary Secondary Primary

3.2.5 Remediation Basis for the Dave Johnston Plant Units 1, 2, 3, and 4
For the purposes of this study at the Dave Johnston Plant, the word
“remediation” refers to the reclamation of the property to the desired end-use
and/or the reversal or stopping of damage to the environment. The following
remediation basis outlines: the general approach to determining remediation
needs to address soil, surface water, and groundwater impacts; the anticipated
remediation/reclamation efforts to be performed after demolition completion;
describes the required condition of the power plant to provide the proper site
controls to facilitate the long-term site basis, and includes the site monitoring and
access controls needed during remediation activities.
Environmental Permit Closure
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An initial step in determining the anticipated closure/remediation needs for the
site includes compiling a detailed summary of the existing environmental permits.
As part of the Phase II decommissioning study site inspections, the existing
environmental permits for the plant will be reviewed to determine the permit
closure requirements for engineering cost estimate evaluation.
Establishment of Remediation Cleanup Goals
Based on the assumption that the selected long-term site basis will be restoration
to “brownfield conditions”, it is assumed for the purpose of this study that the
remediation cleanup target goals will be based on an industrial exposure/re-use
scenario. Following the final decision to decommission the plant, it is
recommended that the site be evaluated to determine the best regulatory option
to guide the closure. There are two primary regulatory options to evaluate with
the Wyoming Department of Environmental Quality (WDEQ): 1. Closure of the
site through the use of existing permits, permit modifications, or new permit
applications; or 2. Enter the WDEQ Voluntary Remediation Program (VRP). A
pre-application meeting should be requested with the WDEQ to discuss the
appropriateness of the VRP to meet the site closure goals.
For the purpose of this study, it is assumed that the VRP is the best option. The
final VRP agreement will clearly define remediation cleanup goals, engineering
controls, institutional controls, and post-closure care requirements, as applicable.
The engineering cost estimate evaluation will include estimated costs for the
development of the VRP application, application fees, and payment of WDEQ
department costs for the department’s oversight of the voluntary remediation.
Environmental Assessment Needs
Following the completion of a VRP application and approval of eligibility by
WDEQ, a site characterization is required that includes the following:
• Data and information gathering;
• Development of a Site Conceptual Model; and
• Preparation of a Site Characterization Work Plan that meets the performance criteria outlined by the VRP.
The performance criteria include:
• Site setting,
• Known and potential sources of contamination,
• Nature and distribution of contaminants and media properties,
• And human and ecological receptors.
To support environmental assessment needs, a Limited Phase I Environmental
Site Assessment should be completed, prior to plant decommissioning, that
evaluates recognized environmental conditions for all major site features (e.g.,
settling ponds, scrubber ponds, storm water ponds, etc.) and all of the storage
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tanks identified in the plant’s Spill Prevention Control and Countermeasures
(SPCC) Plan.
For the pending engineering cost estimate evaluation (Phase II), no
environmental assessment activities are needed at this time. The engineering
cost estimate evaluation will include line item environmental assessment costs
based on PacifiCorp provided information regarding any documented releases
and professional experience from site assessments of similar scale.
Completed, On-going or Pending Remediation Projects
Information has been requested, but only partially provided, regarding any
completed, on-going, or pending remediation projects at the plant. This
information, along with a summary of any existing RCRA Solid Waste
Management Units (SWMUs), will be needed to support the engineering cost
estimate evaluation. Additionally, any previously completed remediation
evaluations or budgetary cost estimates should be provided for reference. Based
on the preliminary information, there is an on-going remediation project from a
large oil release and three of the five landfills have been closed.
Anticipated Remediation Projects
The following is a list of anticipated remediation projects that will be included as
line items in the engineering cost estimate evaluation:
• Completion of the on-going closure and remediation of the large oil release
per the VRP agreement
• Closure and reclamation of the eight coal combustion residuals (CCR) ponds
(Pond 4A, Pond 4B, Clear Pond 4, Pond 1A, Pond 1B, Clear Pond 1A, Clear
Pond 1B, and the Blowdown Canal) per permit closure requirements (RCRA Subtitle D regulations)
• Closure and reclamation of the two active landfills per permit closure requirements
• Continue the long-term monitoring and maintenance programs for the three closed landfills
• Continue the long-term monitoring programs for all site areas with on-going groundwater monitoring programs
• Removal and reclamation of the railroad spurs located within the site boundaries
• Closure of the ash silo storage areas
• Closure of the Main Fuel Oil Storage Tank A,, Fuel Oil Tank C, fuel oil
pipeline, and the Ignition Oil Tank
• Closure of the coal yard maintenance building area
• Closure of the used oil collection area
• Closure of the bottom ash pond
• Closure of the heavy equipment maintenance shop area
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• Closure of the hazardous materials storage area
• Closure of the construction fuel storage area
• Closure of the three coal ready pile areas
Potential Cost Savings
The development of a site-wide final grading plan is recommended. The final
grading plan would evaluate cut-and-fill opportunities on the property to provide
soil cover materials to reduce the material costs for the cap-and-closure of the
existing landfills and closure of existing ponds.
Site Controls
The site will be remediated to VRP determined industrial cleanup standards
which will be protective for an industrial use exposure scenario. Site controls will
be developed on an as needed basis following soil sampling in potential
impacted areas. The foundation slabs will be left in place, providing an
engineered control to limit exposure. Final site grading will be designed to
mitigate erosion issues and reduce long-term maintenance costs. Long-term
monitoring and maintenance of the capped landfills will be estimated. Existing
site controls, such as security fencing, will be left in place and maintenance costs
estimated.
Site Monitoring and Access Controls
Site monitoring needs are unknown at this time and will be based on the
requirements of completed remediation projects. Access control during
remediation activities and post-closure monitoring will be included as a line item
cost.
3.2.6 Assumptions
(Reserved Pending Client Discussion)
3.3 Currant Creek
3.3.1 Long-term Site Basis for the Currant Creek Plant
Numerous options exist for development of the long-term site basis. Options that
may be available to the Owner include the following:
• Restoration to green-field conditions;
o Back to natural (native conditions)
• Restoration to brown-field conditions;
o Property is prepared for reuse as an industrial facility (as determined
by individual state and Federal requirements)
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• Development of alternate commercial/industrial use under a lease agreement;
o Retain property as an investment for reuse
• Site divestiture;
o Complete turnover of property to another entity

Until these alternatives can be further explored with the Owner, and for initial
pricing purposes, CB&I assumes that the preferred long-term site basis is
associated with restoration to “brown-field conditions”, generally meaning there
are use or development restrictions on the site, with complete removal of site
structures to top of slab. This post-closure condition will include perimeter control
with remediation efforts completed to remove direct contact exposure pathways
associated with legacy operations. CB&I also assumes that distribution and
transmission assets will remain operational at the plant. This assumption affects
scope assumptions associated with the development of the decommissioning
basis, the demolition basis, and the remediation basis as well.
3.3.2 Decontamination of the Currant Creek Plant
At the Currant Creek Plant, activities associated with decommissioning,
demolition preparation, equipment conditioning, and demolition may generate a
variety of solid, universal and hazardous waste materials.
The decontamination basis includes cleanup, removal and disposition of
materials that require special handling or disposal prior to demolition. The
decontamination basis describes the required condition of the power plant with
regard to hazardous materials, oils, fuels, and regulated wastes and materials
prior to the start of decommissioning and the start of demolition. The
decontamination basis specifically addresses the type of hazardous material, as
well as the source. The types of hazardous materials may include lead,
asbestos, polychlorinated biphenyls (PCB), chlorofluorocarbons (CFC), radio
isotopes, oils, fuels and miscellaneous hazardous materials such as mercury,
acid, caustic, solvents and other materials. The sources of PCBs are expected
to include, but may not be limited to, lamp fixtures and ballasts and the sources
of CFC are expected to include, but may not be limited to, air conditioning
systems and air conditioning compressor oils.
The decontamination basis includes consideration of the processes and
procedures for the identification, segregation, stockpiling, containerization of
hazardous materials, waste characterization required for waste classification, and
off-site disposal. Batteries, mercury containing equipment, lamps/bulbs, PCB
contaminated oil, and any other miscellaneous universal wastes requiring
disposal due to demolition will be priced to include, handling, transportation,
labor, and proper disposal.
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As required by 40 CFR Part 61 Subpart M, also known as the National Emission
Standard for Hazardous Air Pollutants (NESHAP), asbestos containing materials
that may become damaged or friable during demolition activities must be
removed prior to demolition. The decontamination basis will include the
consideration of asbestos abatement requirements based on materials identified
in the ACM survey provided by PacifiCorp and quantified by CB&I during the site
visit, which will not include asbestos sampling.
3.3.3 Decommissioning Basis for the Currant Creek Plant
For the purposes of this discussion decommissioning is defined as follows:
• Decommissioning – to render a facility safe and environmentally
compliant (neutral) through equipment/facility de-energization, removal of
environmental liabilities, and perimeter security.
The decommissioning basis is developed based on the selected long-term site
basis and determination of demarcation between decommissioning and utility
terminations prior to demolition.
The decommissioning basis will identify requirements for taking the Current
Creek Facility from their current state to a condition where the units and
associated powered equipment have been permanently de-energized and
process related chemicals, fuels, waste and residual materials have been
removed. The decommissioning basis will address utility systems isolation and
relocation, and asset recovery, as well as the de-energization of each unit, i.e.
execution of separation from the transmission yard.
System Layup
The decommissioning basis will address the identification of equipment and
systems requiring layup prior to demolition and will define demolition contractor
responsibilities for completing the work. The decommissioning basis will identify
requirements for the aboveground and belowground utility cut-and-cap and
isolation to be conducted as part of the decommissioning process that will
address electrical systems, fuel systems, water, communications, and related
underground piping and duct banks. The utility cut-and-cap program will address
required disconnections, isolation, cut and capping of utility services required
prior to abatement and/or demolition activities.
Asset Recovery
Asset recovery is the process of assigning values to systems and components
through detailed inventories, prior marketing, and available resources, removing
components and the subsequent sale of those items.
Motors, pumps, electrical gear and machine shop equipment can be used across
many industries and can be recovered for more value than scrap. The asset
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recovery phase allows for potential recovery of higher return back to the owner,
as long as the equipment is in proper working order.
Current Creek asset recovery phase will be to perform an initial system by
system walk down to get an inventory list.
Asset recovery should start before the units are brought off-line, therefore
allowing the asset recovery contractor time to inventory create marketing
materials and align scrap material vendors. This step allows the greatest
flexibility for return on scrap and sale values.
A possible entire facility sale can be considered, but this option requires
considerable marketing efforts. The marketing effort should be started very early
in the planning stage. Engineering support for the transfer should be negotiated
with a potential buyer early in the process
Removal of Solid Fuels
The demolition design will address the requirements for the removal of all
environmental waste solids and liquids encountered throughout the facility. The
Currant Creek plant uses no solid fuels to power its operations. Instead, natural
gas is used as the only fuel as opposed to coal burning. However, an
assessment of other fuels used on site will be performed and will address the
characterization of all materials, the sampling protocols required for disposal
acceptance, and the anticipated disposition of the materials offsite.
Transportation and disposal entities must be identified along with the
requirements for proper preparation and handling methods to be used.
The demolition basis for the Currant Creek Plant will address all of the
requirements and procedures and costs associated with the disconnection of the
Natural gas pipelines supplying the plant as the primary fuel source for the
operation. This will be presented in the utility cut and cap section of the
demolition section for this plant.
Removal and Disposal of Ash
Currant Creek does not operate on the burning of coal as fuel. Ash is not an item
to be addressed at this plant.
Handling of Asbestos Inside of Equipment and at equipment interfaces
The Currant Creek plant was built post 1980 and therefore should not contain
ACM. However, an assessment of potential ACM will be performed. This will
include wire coated materials or localized pipe insulation should be examined.
Closing of Raw Water, Evaporation and Other Ponds
The decommissioning basis will address the removal of all raw water ponds from
the footprint of the Currant Creek facility. An assessment will be performed that
reviews the as-built drawings for impervious liners underlying the holding ponds
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slated for potential removal and restoration. Material volumes slated for offsite
disposal acceptance will be estimated along with transportation and disposal
costs defined if they should apply at this site.
The decommissioning basis will address the requirements for a Soil Erosion and
Sediment Control Plan (SESCP) outlining all requirements for final restoration of
the facility per state requirements governing closure. The demolition basis
should include the SESCP as part of any reclamation assessment of the site.
All raw water and evaporate basins must be identified along with the
requirements for properly closing all on site ponds and impoundments. The
means and methods of the closure of the ponds and impoundments shall be
addressed as part of the demolition design. The closure plan and design for
these areas must be prepared for approval by the State. The plan must also
address all existing permits terminations and/or modifications to be made during
the site closure process. This process will supplement the task related to the
closeout of all operating permits.
3.3.4 Demolition Design Basis for the Currant Creek Plant
For the purposes of this discussion dismantlement/demolition is defined as follows:

• Dismantlement/Demolition – to remove site infrastructure including
equipment, buildings, storage facilities, etc. Dismantlement activities
focus on revenue generation through initial equipment liquidation
and high value salvage activities, followed by overall facility structural
demolition.
The demolition basis describes the conditions and requirements that must be met
for the safe dismantlement/demolition of the plant, and for the closure and
reclamation of all residual holding ponds including the final long-term and short-
term security measures to be employed at the site upon completion of all
demolition and closure activities. The demolition basis includes a general
description of the activities that the Owner, vendors, and contractors will perform
beginning with the pre-demolition planning activities and throughout the entirety
of the demolition schedule. The demolition basis includes a division of
responsibilities for all activities shown below in Table 3: General Division of
Responsibilities – Currant Creek Plant.
The following specific requirements of the demolition basis are described in the
sections below:
• Demolition Permitting Requirements
• Removal of Solid Fuels
• Removal and Disposal of Ash
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• Handling of Asbestos Inside Equipment and At Equipment Interfaces
• Closing of Raw Water, Evaporation, and Coal Combustion Residuals Ponds
• Reclamation of Underground Infrastructures and Removal of Foundations
• Reclamation of the Site and Final Site Grading
• Installation of Permanent Perimeter Control
• Operating Permit Closeout
• Long-term Access Control
Demolition Permitting Requirements:
The demolition basis will include preparation of a matrix of all required permits
as they relate to the demolition of the Currant Creek Plant to include:
• A list of all required permits necessary for the commencement of demolition activities
• The removal of all solids and liquids required prior to dismantlement
• Federal, State and local agency notifications
• Required submittals for the permit
• Engineering review and approval of the dismantlement approach, means and methods
• Acquisition of the Construction/Demolition Permit
The Permitting matrix will include the following information
• Jurisdiction/Regulated Activity
• Permit/Approval Required
• Submittal Date
• Review Time Required
• Expected Permit Receipt Date
• Assigned Agency Reviewer
• Status
• Permit Number
• Timing Restrictions
• Operating Permit Closeout Status
• Primary Contact – General
• General Comments
Reclamation of Industrial and Coal Combustion Residuals Landfills
There are no coal combustion residual landfills present at Currant Creek.
Removal of Underground infrastructures and Removal of Foundations.
If required by the selected long-term site basis, the demolition basis will include
identification of all underground infrastructures in the form of piping, raceways,
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utilities and foundations on a series of drawings showing all utility terminations
and abandonments. A licensed utility locator service should be used by the
Owner to identify all subsurface items that require dismantlement. Drawings
supplied by the Owner will require review to determine the removal criteria of all
structural foundations and infrastructure slated for final removal post structural
dismantlement. The design basis will include identification of the means and
methods for removal of the underground infrastructures and foundations, as well
as for the disposition of all process materials, such as concrete. In addition,
consideration will be given to any aspects of material reuse on site, such as the
necessary preparation and use of process backfill materials that can remain as
part of the final reclamation of the site.
Reclamation of the Site and Final Site Grading
The demolition basis will address final dismantlement of the plant to grade and
consideration of preparation of a final site grading plan that identifies all finished
grades after all structural foundations and subsurface infrastructure has been
removed, as well as materials slated for use to accomplish final grades.
Incorporation of the final reclamation of the retention basins, landfill areas or
impoundments must be included as part of the closure of the site.
Installation of Permanent Perimeter Control
The demolition basis will address the final perimeter control recommended for
the site. If the fencing is the primary means of establishing perimeter control,
fencing plan must include all specifications of the fencing required for installation
including all gates and appurtenances. Potential sources of perimeter control
devices to be used will be discussed as part of the demolition basis.
Operating Permit Closeout
The demolition basis will include as part of the permit matrix, the status of closure
of all operating permits. All existing permits will be listed with their respective
dispositions inclusive of lead times with commentary that provides any issues
and issue resolutions. The matrix should be maintained by PacifiCorp’s
contractors for the duration of the project through the final reclamation phase.
Long-term Access Control
The demolition basis will include consideration of the long-term measures that
will be employed for ensuring adequate access control of the site once the
perimeter control measures have been installed. These measures will include an
inspection and maintenance schedule that will be required once the facility is
finally retired.
3.3.4.1 Design Process Implementation
Detailed process steps of the Design are to be followed and include:
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• Assignment of a Project Manager – PacifiCorp Employee or Third Party
• Early involvement of the Engineering and Construction group
• Determination of demolition scope and building specifications
• Number of Phases involved in the demolition.
• Type of buildings slated for removal.
• Number of employees, executive management, management
• Creation of an internal project team (incorporates all functions)
• Assignment of Third Party Technical Advisor
• Tendering of demolition firms (at least three)
• Design development and final design approval
• Application for permits from all local government agencies
• Demolition
• Asset Recovery
• Reclamation and Restoration
• Long term site security disposition
3.3.4.2 Demolition Design
This guideline, along with PacifiCorp’s Basis of Demolition Design
Specification documents shall be followed during the design phase of the
Currant Creek Generation Facility Decommissioning, Demolition and
Reclamation project as follows:
• Design the means and methods to accomplish the decommissioning
of the plant to include the removal of any fuels, fluids, and gases that are environmentally determined to be hazardous prior to the
demolition of the support building and the power block of the plant.
• As part of the overall design plan, civil works related to reclamation activities including assessment of site conditions, anticipated grading
and drainage considerations, underground utilities, roads, parking lots, walkways, signage, fencing, security gates and barriers.
Reclamation processes and methods will need to be considered and
identified by specification.
• All local regulatory codes and laws shall be followed. All PacifiCorp
standards shall be followed as a minimum.
• During the design stage special attention shall be paid to the
following:
a. Final approval of all site plans and approvals;
b. Health and Safety including all Lock Out/Tag Out procedures
identified along with a procedure that interfaces plant requirements. All procedures are to be OSHA compliant;
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c. Permitting – Application of all applicable permits required to
perform the closure of the coal pile areas, retention basins and impoundments, site decommissioning and demolition including
requirements that address implosive demolition if undertaken;
d. Water – Access to potable and reliable water supply;
e. Electricity – Access to adequate supply based on the power
required by the facility and design of proper temporary
electrical systems; (or permanent environmental monitoring systems if required).
f. Additional utility cut and caps required as part of the
dismantlement;
g. Closure and removal (if required) of all subsurface piping and
concrete foundation and footing to a depth of 3 feet below
grade;
h. Closure and/or removal of the plant water intake structures
particularly piping from the water production wells offsite;
i. Review of all demolition sequencing by a certified structural engineer licensed in the State of Wyoming;
j. Dangerous Goods Removal, Handling (characterization) and, Disposal;
k. Final site grading;
l. Final reclamation;
m. Short term and long term site security.
n. The basis for Contractor qualifications.
3.3.4.3 Demolition Sequencing
The following describe the General requirements for the sequencing of
construction activities that will be required as part of the Demolition
Design Basis.
Pre Demolition Mobilization Tasks
The demolition design basis shall include a table showing the general
division of responsibilities assigned between PacifiCorp, the Engineer and
the Contractor. This should be prepared by the demolition contractor and
presented in the form of an Organization Chart with tie lines clearly
identifying the hierarchy of reporting inclusive of roles and responsibilities
for the demolition work. The demolition basis will include the basis and
assumptions in the form of a plan submittal for the management and
handling of all salvage and recycled materials.
The Design Basis should address the required submittals for the work at
Currant Creek Plant. The submittals should encompass the following:
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Pre Demolition Mobilization Submittals:
• Site Specific Health and Safety Plan (SSHASP)
• Permitting Matrix and Status
• Demolition Work Plan
• Permitting Plan
• Salvage Management Plan
• Site Grading and Reclamation Plan
Site Setup
Site Setup should be addressed in the Design Basis and clearly identify
the tasks to be performed in preparation for demolition. Typically during
site setup the contractor should identify in the pre mobilization plans all
aspects related to the mobilization of manpower, equipment and materials
that will be required as part of the work. Additionally, tasks related to final
preparations prior to the start of dismantlement must also be considered
in the design such as utility cuts and capping, and de-energizing the
station to a “dark” state condition.
Prior to dismantlement, the design basis must address the steps and
requirements for the removal of all assets. As part of the Demolition
Work Plan or under a separate header, the removal of assets should also
be addressed. All critical lifts and rigging plans must be submitted to the
start of the dismantlement sequenced activities. Supplemental asbestos
abatement, if any, must also be part of the dismantlement and addressed
as a contingency.
The design basis must also address post environmental cleaning of the
structure if necessary, and the methodology to be employed for
controlling fugitive dust emissions during dismantlement. As part of the
SSHASP, air monitoring for fugitive dust and particulate emissions must
be included for the purposes of personal protection of the workers and the
community in accordance to OSHA requirements.
Plant Dismantlement
The demolition design basis shall address the recommended sequence of
activities to be undertaken by the selected demolition contractor. In
particular, the design basis must address the methodology for the
removal of:
Support Structures and outer buildings such as:
• Emission control structures;
• Transformers;
• Electrical Transmission Towers to be removed;
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• Utility cut and cap;
• Water intake System;
• Pumping Stations;
• Shops and Administrative Office Structures;
• On site Water Treatment;
• Transmission substations
• Fire suppression System;
Structures related to the Power Block
• Turbines;
• Turbine Hall;
• Condensers;
• Above ground and underground storage tanks;
• Turbine Pedestals and Gantry Crane;
• Turbine Building Structure;
• Boilers;
• Boiler Plant Structure;
• Control Center;
• Stacks
• Removal of Interior Electrical Cabling;
• Removal of the Fire Suppression System.
• Salvage Management and loadout
The design basis will also address the preferred methodology of
dismantlement to be acceptable given the structural makeup of all
aspects of the plant. Dismantlement scenarios may involve a piecemeal
removal of structures, removal of all interior appurtenances followed by a
controlled drop of the structure without explosives, or total implosion
scenario.
The specifications shall define all of the requirements necessary for
conducting and evaluating all rigging and critical lifts. The review and
approval procedure must be identified as part of the demolition design
basis to ensure safe operations during dismantlement activities
regardless of the method of dismantlement chosen by the contractor.
Structural Implosion
The design basis is to include the considerations required for the
implosion of the structures if not achievable by conventional
dismantlement methods. At this time is anticipated that Currant Creek
can be dismantled using conventional demolition equipment. The basis
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for a controlled dismantlement via implosion and the requirements thereof
should consider:
• The methodology for the development of the Implosion model;
• Structural Engineering Assessment of the implosion scenario;
• Health and safety;
• Fugitive dust control and monitoring;
• Explosive charges to be used;
• Community Relations.
Engineering cost Estimates
The design basis shall estimate both cost and duration of all
dismantlement scenarios as described above. A base case estimate is to
be developed using a conventional, piecemeal dismantlement scenario
with an additional option to implode the structures if practicable. The
estimate(s) shall be broken out in sufficient detail to describe the work
breakdown structure for the dismantlement phase of work. All labor and
equipment shall include buildups using raw labor rates with fringe
benefits. Raw equipment and material costs shall also be presented.
Standard rental rates will be used to estimate equipment use for the
project. A markup of 8% shall be applied onto the total cost that will be
used to develop a final value for the dismantlement estimate.
All estimates should also be accompanied by a critical path project
schedule that will show the duration and interrelationship of all tasks
related to dismantlement.
Table 3 – General Division of Responsibilities Currant Creek Plant
Item Task Comment
1 Support Primary Secondary
2 Primary (I)
3 Removal of Fuels, if any Secondary Primary
4 Secondary Primary
5 Support Primary I)
7 Site Reclamation Support
8 Finished Site Grade Support
9 Support Secondary Primary (I)
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Item Task Comment
13 Secondary Primary
14
Supplemental/Confirmatory
Asbestos Characterization (if any)
Secondary
(R, A)
Secondary (R,
A, O) Primary (I)
expected in
quantity due to
the recent age of the Currant Creek
15 Demolition Submittals Secondary (R,A) Primary (I)
16 Construction Sequencing Primary (I)
18 Secondary Secondary Primary

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3.3.5 Remediation Basis for the Currant Creek Plant
For the purposes of this study at the Currant Creek Plant, the word “remediation”
refers to the reclamation of the property to the desired end-use and/or the
reversal or stopping of damage to the environment. The following remediation
basis outlines: the general approach to determining remediation needs to
address soil, surface water, and groundwater impacts; the anticipated
remediation/reclamation efforts to be performed after demolition completion;
describes the required condition of the power plant to provide the proper site
controls to facilitate the long-term site basis, and includes the site monitoring and
access controls needed during remediation activities
Environmental Permit Closure
An initial step in determining the anticipated closure/remediation needs for the
site includes compiling a detailed summary of the existing environmental permits.
As part of the Phase II decommissioning study site inspections, the existing
environmental permits for the plant will be reviewed to determine the permit
closure requirements for engineering cost estimate evaluation.
Establishment of Remediation Cleanup Goals
Based on the assumption that the selected long-term site basis will be restoration
to “brownfield conditions”, it is assumed for the purpose of this study that the
remediation cleanup target goals will be based on an industrial exposure/re-use
scenario. Following the final decision to decommission the plant, it is
recommended that the site be evaluated to determine the best regulatory option
to guide the closure. There are two primary regulatory options to evaluate with
the Utah Department of Environmental Quality (DEQ): 1. Closure of the site
through the use of existing permits, permit modifications, or new permit
applications; or 2. Enter the Utah DEQ Voluntary Cleanup Program (VCP). A
pre-application meeting should be requested with the Utah DEQ to discuss the
appropriateness of the VCP to meet the site closure goals.
For the purpose of this study, it is assumed that the VCP is the best option. The
final VCP agreement will clearly define remediation cleanup goals, engineering
controls, institutional controls, and post-closure care requirements, as applicable.
The engineering cost estimate evaluation will include estimated costs for the
development of the VCP application, application fees, and payment of Utah DEQ
department costs for the department’s oversight of the voluntary cleanup.
Environmental Assessment Needs
To support the VCP application, an environmental assessment is required that
includes the following:
• A legal description of the site;
• A description of the physical characteristics of the site;
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• The operational history of the site to the extent known by the applicant;
• Information of which the applicant is aware concerning the nature and extent
of any relevant contamination or release at the site and immediately
contiguous to the site, and where the contamination is located; and
• Relevant information of which the applicant is aware concerning the potential
for human and environmental exposure to contamination at the site.
A limited Phase I Environmental Site Assessment should be completed, prior to
plant decommissioning, that evaluates recognized environmental conditions for
all major site features (e.g., chemical storage, hazardous waste storage, oil water
separator tank, etc.) and all of the storage tanks identified in the plant’s Spill
Prevention Control and Countermeasures (SPCC) Plan.
For the pending engineering cost estimate evaluation (Phase II), no
environmental assessment activities are needed at this time. The engineering
cost estimate evaluation will include line item environmental assessment costs
based on PacifiCorp provided information regarding any documented releases
and professional experience from site assessments of similar scale.
Completed, On-going or Pending Remediation Projects
Based on preliminary information provided from PacifiCorp, there are no
completed, on-going, or pending remediation projects at the Currant Creek Plant.
Anticipated Remediation Projects
The Currant Creek Plant was commissioned in 2005. Due to the short history of
this modern natural gas power plant, there are no anticipated remediation
projects. For planning purposes, a line item contingency will be developed to
provide a fund for potential remediation projects that may be needed during site
closure activities. Once a review of the active environmental permits is
completed during Phase II, line items will also be included to cover any required
permit closure costs.
Site Controls
The site will be remediated to VCP determined industrial cleanup standards
which will be protective for an industrial use exposure scenario. Site controls will
be developed on an as needed basis following soil sampling in potentially
impacted areas. The foundation slabs will be left in place, providing an
engineered control to limit exposure. Final site grading will be designed to
mitigate erosion issues and reduce long-term maintenance costs. Long-term
monitoring and maintenance of the capped landfills will be estimated. Existing
site controls, such as security fencing, will be left in place and maintenance costs
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Site Monitoring and Access Controls
Site monitoring needs are unknown at this time and will be based on the
requirements of completed remediation projects. Access control during
remediation activities and post-closure monitoring will be included as line item
costs.
3.3.6 Assumptions
(Reserved Pending Client Discussion)
3.4 Huntington Plant Units 1 and 2
3.4.1 Long-term Site Basis for the Huntington Plant Units 1 and 2
Numerous options exist for development of the long-term site basis. Options that
may be available to the Owner include the following:
• Restoration to green-field conditions;
o Back to natural (native conditions)
• Restoration to brown-field conditions;
o Property is prepared for reuse as an industrial facility (as determined by individual state and Federal requirements)
• Development of alternate commercial/industrial use under a lease agreement;
o Retain property as an investment for reuse
• Site divestiture;
o Complete turnover of property to another entity
Until these alternatives can be further explored with the Owner, and for initial
pricing purposes, CB&I assumes that the preferred long-term site basis is
associated with restoration to “brown-field conditions”, generally meaning there
are use or development restrictions on the site, with complete removal of site
structures to top of slab. This post-closure condition will include perimeter control
with remediation efforts completed to remove direct contact exposure pathways
associated with legacy operations. CB&I also assumes that distribution and
transmission assets will remain operational at the plant. This assumption affects
scope assumptions associated with the development of the decommissioning
basis, the demolition basis, and the remediation basis as well.
3.4.2 Decontamination of Huntington Plant
At the Huntington Plant, activities associated with decommissioning, demolition
preparation, equipment conditioning, and demolition may generate a variety of
solid, universal and hazardous waste materials.
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The decontamination basis includes cleanup, removal and disposition of
materials that require special handling or disposal prior to demolition. The
decontamination basis describes the required condition of the power plant with
regard to hazardous materials, oils, fuels, and regulated wastes and materials
prior to the start of decommissioning and the start of demolition. The
decontamination basis specifically addresses the type of hazardous material, as
well as the source. The types of hazardous materials may include lead,
asbestos, polychlorinated biphenyls (PCB), chlorofluorocarbons (CFC), radio
isotopes, oils, fuels and miscellaneous hazardous materials such as mercury,
acid, caustic, solvents and other materials. The sources of PCBs are expected
to include, but may not be limited to, lamp fixtures and ballasts and the sources
of CFC are expected to include, but may not be limited to, air conditioning
systems and air conditioning compressor oils.
The decontamination basis includes consideration of the processes and
procedures for the identification, segregation, stockpiling, containerization of
hazardous materials, waste characterization required for waste classification, and
off-site disposal. Batteries, mercury containing equipment, lamps/bulbs, PCB
contaminated oil, and any other miscellaneous universal wastes requiring
disposal due to demolition will be priced to include, handling, transportation,
labor, and proper disposal.
As required by 40 CFR Part 61 Subpart M, also known as the National Emission
Standard for Hazardous Air Pollutants (NESHAP), asbestos containing materials
that may become damaged or friable during demolition activities must be
removed prior to demolition. The decontamination basis will include the
consideration of asbestos abatement requirements based on materials identified
in the ACM survey provided by PacifiCorp and quantified by CB&I during the site
visit, which will not include asbestos sampling.
3.4.3 Decommissioning Basis for the Huntington Plant Units 1&2
For the purposes of this discussion decommissioning is defined as follows:
• Decommissioning – to render a facility safe and environmentally
compliant (neutral) through equipment/facility de-energization, removal of
environmental liabilities and perimeter security.
The decommissioning basis is developed based on the selected long-term site
basis and determination of demarcation between decommissioning and utility
terminations prior to demolition.
The decommissioning basis will identify requirements for taking the Huntington
Plant Units 1&2 from their current state to a condition where the units and
associated powered equipment have been permanently de-energized and
process related chemicals, fuels, waste and residual materials have been
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removed. The decommissioning basis will address utility systems isolation and
relocation, and asset recovery, as well as the de-energization of each unit, i.e.
execution of separation from the transmission yard.
System Layup
Initial system layup for Huntington Plant Units 1&2, should represent the final
configuration of the plant. The goal is to eliminate any potential energy source
from the facility. Initial plan would be to put in place fire side, water side,
scrubber, electrical, and fuel Lock Out Tag Out’s (LOTO’s). This would allow a
chance to do a stepped approach to removing energy sources.
Initial system layup should include burning all remaining coal in surge bins and
daily silos. This removes potential hot-spot issues with coal remaining in closed
environments for extended periods.
Depending on time of year, water would need to be drained from all process
equipment. This includes all water cooled bearings, condensation return piping,
service water lines, pumps, un-needed fire water points, potable water piping,
and essentially anything that has freeze protection wrapping.
Electrical is usually the longest lead item for de-energizing a facility. If the entire
facility including switchyards are coming off-line, electrical de-energized can be
completed early. This will probably not be the case and therefore will have to
initially proceed on the stepped down LOTO approach. Once switchyards are
isolated the electrical isolation process can proceed.
Compressed air is an essential tool for an operating plant. The compressed air
lines run throughout the facility and can provide a much needed energy source
during decommissioning. It is proposed that the PacifiCorp decommissioning
contractor eliminate this source early. The reason is two-fold; first it eliminates a
potential energy source and therefore a safety issue. Second it is also an energy
opportunity cost and therefore will cost PacifiCorp money to generate
compressed air. It is suggested the decommissioning contractor supply their
own compressed air locally when needed.
The layup of Huntington Plant Units 1&2 should include removal of coal from
belts, water from all exposed piping and pumps, LOTO electrical, (air gap, if
possible, switchyard from units). The goal is to use the least amount of LOTO’s
as possible. This allows greater freedom of access to the decommissioning
contractor.
The last item at Huntington Plant Units 1&2 for system layup would be any utility
reroutes. If the entire facility comes offline at the same time utility reroutes may
not be needed. If it is a phased approach, all utility reroutes will be required to be
engineered. This is about a year long process and if multiple owners are
involved it can take a little longer.
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Asset Recovery
Asset recovery is the process of assigning values to systems and components
through detailed inventories, prior marketing, and available resources, removing
components and the subsequent sale of those items.
Motors, pumps, electrical gear and machine shop equipment can be used across
many industries and can be recovered for more value than scrap. The asset
recovery phase allows for potential recovery of higher return back to the owner,
as long as the equipment is in proper working order.
Huntington Units 1&2 asset recovery phase will be to perform an initial system by
system walk down to get an inventory list. The age of the Huntington Units 1&2
plant will determine viability of asset sales or scrap values.
Asset recovery should start before the units are brought off-line, therefore
allowing the asset recovery contractor time to inventory create marketing
materials and align scrap material vendors. This step allows the greatest
flexibility for return on scrap and sale values.
A possible entire facility sale can be considered, but this option requires
considerable marketing efforts. The marketing effort should be started very early
in the planning stage. Engineering support for the transfer should be negotiated
with a potential buyer early in the process.
Removal of Solid Fuels
Initial removal of fuels depends on PacifiCorp. The final off-line date can best
prepare the Huntington Plant Units 1&2 for solid fuel removal. CB&I
recommends that Huntington Plant Units 1&2 coordinate with PacifiCorp energy
marketing very early in the process to effectively manage stockpiled coal. The
best method of elimination is to burn all possible coal stockpiles. If a thirty or
seven day pile is kept on site, plan on suppliers (mine mouth) cease deliveries.
This allows the coal pile to be at a minimum and therefore cost of remediation of
remaining solid fuel can be decreased.
Solid fuels can be removed only by trucking. Since Huntington Plant Units 1&2
is not connected to any mainline, trucking is only effective manner to remove
waste coal/solid fuel.
Lime for scrubber operations can be mitigated in much the same manner that
coal is mitigated. Early offline date determination and working with the supplier
will prevent excess on-hand material. All lime should be slaked even if not used
prior to shut down. Lime slurry can be used as a dust suppressant for roads and
should be considered as a disposal method if possible.
Further analysis of existing protocols will need to be verified to determine ratios
of mixtures of remaining environmental scrubber materials to determine best
method of handling and disposal.
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Removal and Disposal of Ash
Ash can be handled in several methods and may be considered hazardous in the
near future. The easiest method would be to place ash back in mine if possible.
If this is not be feasible at Huntington Plant Units 1&2, disposition by excavation
and trucking is only method feasible. Certified landfills would need to be
determined once an off-line date is proposed. The ash remediation is removal
and over excavation.
Removal and disposal will be further defined upon final Jim Bridger site
determination.
Handling of Asbestos Inside Equipment and At Equipment Interfaces
During the decommissioning process, all Asbestos Containing Materials (ACM)
at interface points (gaskets, immediately adjoining piping, etc…) will be mitigated.
The suspected ACM will be treated as ACM and will be handled accordingly.
Initially most ACM at interface points can be mitigated utilizing a glove-bag
method. If PacifiCorp is utilizing an alliance partner during normal operations or
utilizing PacifiCorp personnel to mitigate interface points, it would be
advantageous to continue this procedure during decommissioning.
If no contract exists at time of decommissioning, a suggested path would be to
get a local contractor on board for small scale asbestos remediation. This allows
greater flexibility on schedule and costs.
Closing of Raw Water, Evaporation and Coal Combustion Residuals Ponds
Huntington Plant Units 1&2 facility includes a main intake pipe that originates at
Electric Lake approximately 18 miles to the north. This pipeline is suggested to
be abandoned in place if possible.
The raw water pond, and 1 small pond should be drained and clean fill placed to
final grade.
Coal residual pond will need to be drained and remediated. This design basis
will be further defined upon final disposition of facility. Initial remediation efforts
would be to drain and then over-excavate, replace with clean fill and reseed to
final grade.
All permits for Huntington Plant Units 1&2 will be determined upon final site
determination. Soil remediation and reseeding efforts should be done with native
grasses to minimize watering after initial germination period.

3.4.4 Demolition Basis for the Huntington Plant Units 1 & 2
For the purposes of this discussion dismantlement/demolition is defined as follows:
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• Dismantlement/Demolition – to remove site infrastructure including
equipment, buildings, storage facilities, etc. Dismantlement activities
focus on revenue generation through initial equipment liquidation
and high value salvage activities, followed by overall facility structural
demolition.
The demolition basis describes the conditions and requirements that must be met
for the safe dismantlement/demolition of the plant, and for the closure and
reclamation of all residual holding ponds including the final long-term and short-
term security measures to be employed at the site upon completion of all
demolition and closure activities. The demolition basis includes a general
description of the activities that the Owner, vendors, and contractors will perform
beginning with the pre-demolition planning activities and throughout the entirety
of the demolition schedule. The demolition basis includes a division of
responsibilities for all activities shown below in Table 4: General Division of
Responsibilities – Huntington Plant Units 1 and 2.
The following specific requirements of the demolition basis are described in the
sections below:
• Demolition Permitting Requirements
• Removal of Solid Fuels
• Removal and Disposal of Ash
• Handling of Asbestos Inside Equipment and At Equipment Interfaces
• Closing of Raw Water, Evaporation, and Coal Combustion Residuals Ponds
• Reclamation of Underground Infrastructures and Removal of Foundations
• Reclamation of the Site and Final Site Grading
• Installation of Permanent Perimeter Control
• Operating Permit Closeout
• Long-term Access Control
Demolition Permitting Requirements:
The demolition basis will include preparation of a matrix of all required permits as
they relate to the demolition of the Huntington Plant Units 1 and 2 to include:
• A list of all required permits necessary for the commencement of demolition activities
• The removal of all solids and liquids required prior to dismantlement
• Federal, State and local agency notifications
• Required submittals for the permit
• Engineering review and approval of the dismantlement approach, means and methods
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• Acquisition of the Construction/Demolition Permit
The Permitting matrix will include the following information
• Jurisdiction/Regulated Activity
• Permit/Approval Required
• Submittal Date
• Review Time Required
• Expected Permit Receipt Date
• Assigned Agency Reviewer
• Status
• Permit Number
• Timing Restrictions
• Operating Permit Closeout Status
• Primary Contact – General
• General Comments
Reclamation of Industrial and Coal Combustion Residuals Landfills
The demolition basis will include the identification and survey of all areas related
to current ash impoundments or landfills. A review of as-built drawings of these
must be reviewed and assessed for final closure criteria development.
Removal of Underground infrastructures and Removal of Foundations.
If required by the selected long-term site basis, the demolition basis will include
identification of all underground infrastructures in the form of piping, raceways,
utilities and foundations on a series of drawings showing all utility terminations
and abandonments. A licensed utility locator service should be used by the
Owner to identify all subsurface items that require dismantlement. Drawings
supplied by the Owner will require review to determine the removal criteria of all
structural foundations and infrastructure slated for final removal post structural
dismantlement. The design basis will include identification of the means and
methods for removal of the underground infrastructures and foundations, as well
as for the disposition of all process materials, such as concrete. In addition,
consideration will be given to any aspects of material reuse on site, such as the
necessary preparation and use of process backfill materials that can remain as
part of the final reclamation of the site.
Reclamation of the Site and Final Site Grading
The demolition basis will address final dismantlement of the plant to grade and
consideration of preparation of a final site grading plan that identifies all finished
grades after all structural foundations and subsurface infrastructure has been
removed, as well as materials slated for use to accomplish final grades. The
Deer Creek Mine located 2.4 miles away from the plant is not part of the design
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basis for this plant site. However, the conveyance system is to be included as
part of the asset valuation and demolition scope for the closure of the Huntington
Plant.
Installation of Permanent Perimeter Control
The demolition basis will address the final perimeter control recommended for
the site. If the fencing is the primary means of establishing perimeter control,
fencing plan must include all specifications of the fencing required for installation
including all gates and appurtenances. Potential sources of perimeter control
devices to be used will be discussed as part of the demolition basis.
Operating Permit Closeout
The demolition basis will include as part of the permit matrix the status of closure
of all operating permits. All existing permits will be listed with their respective
dispositions inclusive of lead times with commentary that provides any issues
and issue resolutions. The matrix should be maintained by PacifiCorp’s
contractors for the duration of the project through the final reclamation phase.
Long-term access control
The demolition basis will include consideration of the long-term measures that
will be employed for ensuring adequate access control of the site once the
perimeter control measures have been installed. These measures will include an
inspection and maintenance schedule that will be required once the facility is
finally retired.
The Deer Creek Mine located 2.4 miles away from the plant is not part of the
design basis for this plant site. However, the conveyance system is to be
included as part of the asset valuation and demolition scope for the closure of the
Huntington plant.
3.4.4.1 Demolition Design Process Implementation
Detailed process steps of the Demolition Design are to be followed and
include:
• Assignment of a Project Manager – PacifiCorp Employee or Third
Party
• Early involvement of the Engineering and Construction group
• Determination of demolition scope and building specifications
• Number of Phases involved in the demolition.
• Type of buildings slated for removal.
• Number of employees, executive management, management
• Creation of an internal project team (incorporates all functions)
• Assignment of Third Party Technical Advisor
• Tendering for demolition firms (at least three)
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• Design development and final design approval
• Application for permits from all local government agencies
• Demolition
• Asset Recovery
• Reclamation and Restoration
• Long term site security disposition
3.4.4.2 Demolition Design
This section describes a guideline that, along with PacifiCorp’s Basis of
Demolition Design Specification documents, should be followed during
the demolition design phase and incorporated into the Project Plan to be
prepared by PacifiCorp’s contractor. The demolition design should
include the following elements and considerations:
• Design the means and methods to accomplish the decommissioning
of the plant to include the removal of liquid and solid fuels, fluids, and
gases that are environmentally determined to be hazardous prior to the demolition of the support building and the power block of the plant.
• As part of the overall design plan, civil works related to reclamation activities including assessment of site conditions, anticipated grading and drainage considerations, underground utilities, roads, parking
lots, walkways, signage, fencing, security gates and barriers. Reclamation processes and methods will need to be considered.
• All local regulatory codes and laws shall be followed. All PacifiCorp standards shall be followed as a minimum.
• During the design stage special attention shall be paid to the following:
a. Final approval of all site plans and approvals;
b. Health and Safety including all Lock Out/Tag Out procedures identified along with a procedure that interfaces plant
requirements. All procedures are to be OSHA compliant;
c. Permitting – Application of all applicable permits required to perform the closure of the coal pile areas, retention basins and
impoundments, site decommissioning and demolition including
requirements that address implosive demolition if undertaken;
d. Water – Access to potable and reliable water supply;
e. Electricity – Access to adequate supply based on the power
required by the facility and design of proper temporary electrical systems; (or permanent environmental monitoring
systems if required).
f. Utility cut and cap;
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g. Closure and removal (if required) of all subsurface piping and
concrete foundation and footing to a depth of 3 feet below grade;
h. Closure and/or removal of the plant water intake structures;
i. Review of all demolition sequencing by a certified structural engineer licensed in the State of Wyoming;
j. Dangerous Goods Removal, Handling (characterization) and,
Disposal;
k. Final site grading;
l. Final reclamation;
m. Short term and long term site security.
n. The basis for contractor qualifications.
3.4.4.3 Demolition Sequencing
This section describes the General requirements for the sequencing of
construction activities that will be incorporated as part of the Demolition
Basis.
Pre-Demolition Mobilization Tasks
The demolition basis will include a table showing the general division of
responsibilities assigned between PacifiCorp, the Engineer and the
Contractor. This table should be prepared and finalized by the demolition
contractor and presented in the form of an Organization Chart with tie
lines clearly identifying the hierarchy of reporting inclusive of roles and
responsibilities for the demolition work. The demolition basis will include
the basis and assumptions for the management and handling of all
salvage and recycled materials.
The demolition basis will address the required submittals for the work at
Huntington Plant. The submittals should encompass the following:
Pre-Demolition Mobilization Submittals:
• Project Plan; including plans and specifications for all aspects of the
decontamination, decommissioning, demolition, reclamation, water
management, and assessment and decontamination of the facility
• Site Specific Health and Safety Plan (SSHASP)
• Permitting Matrix and Status
• Demolition Work Plan
• Permitting Plan
• Salvage Management Plan
• Site Grading and Reclamation Plan
Site Setup
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Site setup will be addressed in the demolition basis and will clearly
identify the tasks to be performed in preparation for demolition. Typically
during site setup the demolition contractor should identify in the pre-
mobilization plans all aspects related to the mobilization of manpower,
equipment and materials that will be required as part of the work.
Additionally, tasks related to final preparations prior to the start of
dismantlement must also be considered in the design; examples of these
tasks include utility cuts and capping, de-energizing the station to a “dark”
state condition, identification of all critical lifts and rigging plans submitted
prior to the start of the dismantlement sequenced activities.
The demolition basis will address the steps and requirements for the
removal of all assets prior to dismantlement,. As part of the Demolition
Work Plan or under a separate header, the removal of assets should also
be addressed. The demolition contractor must submit the procedures for
all critical lifts and submit rigging plans prior to the start of the
dismantlement sequenced activities. Supplemental asbestos abatement
must also be part of the dismantlement and addressed as a contingency.
The demolition basis will also address post environmental cleaning of the
structure if necessary, and the requirement for controlling fugitive dust
emissions during dismantlement. As part of the SSHASP prepared by the
demolition contractor, air monitoring for fugitive dust emissions must be
included for the purposes of personal protection of the workers and the
community in accordance to OSHA requirements.
Plant Dismantlement
The demolition basis will address the recommended sequence of
activities to be undertaken by the selected demolition contractor. In
particular, the demolition basis will address the methodology for:
Removal of Support Structures and outer buildings such as:
• Emission control structures;
• Coal handling equipment;
• Transformers;
• Electrical Transmission Towers to be removed;
• Utility cut and cap program (plant wide);
• Water intake System;
• Cooling Towers;
• Pumping Stations;
• Shops and Administrative Office Structures;
• On site Water Treatment;
• Transmission substations
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• Fire suppression System;
Removal of Structures related to the Power Block
• Turbines;
• Turbine Hall;
• Condensers;
• Turbine Pedestals and Gantry Crane;
• Turbine Building Structure;
• Above ground and underground storage tanks
• Boilers;
• Boiler Plant Structure;
• Control Center;
• Stacks
• Removal of Interior Electrical Cabling;
• Removal of the Fire Suppression System.
• Salvage Management and loadout
Reclamation and Closure of the Coal Pile and Ash Basins
• Closure Permitting of basins
• Removal of waste coal product off site
• Backfilling of the Coal Pile footprint
• Final Grading
• Topsoil and Seeding.
The demolition basis will also address the preferred methodology of
dismantlement to be acceptable given the structural makeup of all
aspects of the plant. Dismantlement scenarios may involve a piecemeal
removal of structures, removal of all interior appurtenances followed by a
controlled drop of the structure without explosives, or total implosion
scenario.
The review and approval procedure must be identified as part of the
demolition basis to ensure safe operations during dismantlement activities
regardless of the method of dismantlement chosen by PacifiCorp’s
demolition contractor.
Structural Implosion
The demolition basis will include the considerations required for the
implosion of the structures. The basis for a controlled dismantlement via
implosion and the requirements thereof should consider:
• The methodology for the development of the Implosion model;
• Structural Engineering Assessment of the implosion scenario;
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• Health and safety;
• Fugitive dust control and monitoring;
• Explosive charges to be used;
• Community Relations.
Engineering Cost Estimates
The demolition basis will be developed in such a manner to provide a
baseline for the engineering cost estimate and a high-level schedule to be
developed in Phase II of this project
Table 4 – General Division of Responsibilities Huntington Plant Units 1, and 2
Item Task Comment
1 Support Primary Secondary
2 Support (R) Primary (D) (O) Primary (I)
3 Removal of Solid Fuels Secondary Primary
4 Secondary Primary
5 Handling of Asbestos Secondary Primary
6 Support Primary I)
7 Combust residual Support Primary (D) Secondary (O) Primary (I)
9 Site Reclamation Support
10 Finished Site Grade Support
11 Support Secondary Primary (I)
12 Secondary Primary (D, I)
13 Secondary Primary (D,I)
14 Secondary Primary
15 Abatement Contractor Secondary Primary
16 Primary (I)
17 Demolition Submittals Secondary (R,A) Primary (I)
18 Construction Sequencing Primary (I)
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Item Task Comment
20 Secondary Secondary Primary
3.4.5 Remediation Basis for the Huntington Plant Units 1 and 2
For the purposes of this study, the word “remediation” refers to the reclamation of
the property to the desired end-use and/or the reversal or stopping of damage to
the environment. The following remediation basis outlines: the general approach
to determining remediation needs to address soil, surface water, and
groundwater impacts; the anticipated remediation/reclamation efforts to be
performed after demolition completion; describes the required condition of the
power plant to provide the proper site controls to facilitate the long-term site
basis, and includes the site monitoring and access controls needed during
remediation activities
Environmental Permit Closure
An initial step in determining the anticipated closure/remediation needs for the
site includes compiling a detailed summary of the existing environmental permits.
As part of the Phase II decommissioning study site inspections, the existing
environmental permits for the plant will be reviewed to determine the permit
closure requirements for engineering cost estimate evaluation.
Establishment of Remediation Cleanup Goals
Based on the assumption that the selected long-term site basis will be restoration
to “brownfield conditions”, it is assumed for the purpose of this study that the
remediation cleanup target goals will be based on an industrial exposure/re-use
scenario. Following the final decision to decommission the plant, it is
recommended that the site be evaluated to determine the best regulatory option
to guide the closure. There are two primary regulatory options to evaluate with
the Utah Department of Environmental Quality (DEQ): 1. Closure of the site
through the use of existing permits, permit modifications, or new permit
applications; or 2. Enter the Utah DEQ Voluntary Cleanup Program (VCP). A
pre-application meeting should be requested with the Utah DEQ to discuss the
appropriateness of the VCP to meet the site closure goals.
For the purpose of this study, it is assumed that the VCP is the best option. The
final VCP agreement will clearly define remediation cleanup goals, engineering
controls, institutional controls, and post-closure care requirements, as applicable.
The engineering cost estimate evaluation will include estimated costs for the
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development of the VCP application, application fees, and payment of Utah DEQ
department costs for the department’s oversight of the voluntary cleanup.
Environmental Assessment Needs
To support the VCP application, an environmental assessment is required that
includes the following:
• A legal description of the site;
• A description of the physical characteristics of the site;
• The operational history of the site to the extent known by the applicant;
• Information of which the applicant is aware concerning the nature and extent of any relevant contamination or release at the site and immediately
contiguous to the site, and where the contamination is located; and
• Relevant information of which the applicant is aware concerning the potential for human and environmental exposure to contamination at the site.
A limited Phase I Environmental Site Assessment should be completed, prior to
plant decommissioning, that evaluates recognized environmental conditions for
all major site features (e.g., settling ponds, scrubber ponds, storm water ponds,
etc.) and all of the storage tanks identified in the plant’s Spill Prevention Control
and Countermeasures (SPCC) Plan.
For the pending engineering cost estimate evaluation (Phase II), no
environmental assessment activities are needed at this time. The engineering
cost estimate evaluation will include line item environmental assessment costs
based on PacifiCorp provided information regarding any documented releases
and professional experience from site assessments of similar scale.
Completed, On-going or Pending Remediation Projects
Information has been requested, but not yet provided, regarding any completed,
on-going, or pending remediation projects at the plant. This information, along
with a summary of any existing RCRA Solid Waste Management Units (SWMUs),
will be needed to support the engineering cost estimate evaluation. Additionally,
any previously completed remediation evaluations or budgetary cost estimates
should be provided for reference.
Anticipated Remediation Projects
The following is a list of anticipated remediation projects that will be included as
line items in the engineering cost estimate evaluation:
• Closure and reclamation of the PacifiCorp-Huntington Industrial Waste Class
IIIb Landfill under the permit prescribed closure (RCRA Subtitle D
regulations) – 2 feet of soil cover including 6 inches of top soil (Huntington Power Plant Landfill Operations Plan)
• Long term monitoring of the closed “Old Ash Pile” (non-permitted CCR landfill area)
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• Closure and reclamation of the “New Ash Pile” (non-permitted CCR landfill area) – 1 foot of soil cover including 6 inches of top soil (Huntington Power Plant Landfill Operations Plan)
• Closure of the Huntington Plant Raw Water Settling Pond (Pond #1)
• Closure of the Huntington Plant Evaporation/Storage Pond (Pond #2)
• Closure of the Huntington Plant Duck Pond (Pond #3)
• Closure of the Huntington Plant Electric Lake (Pond #4)
• Closure of the Huntington Plant New Ash Pile Storm Water Pond (Pond #5)
• Closure of the Huntington Plant Race Horse Pond (Pond #6)
• Closure of the Huntington Plant Holding Pond/Basin (Pond #7)
• Closure of the Huntington Plant Lacey’s Lake (Pond #8)
• Closure of the Huntington Plant Scrubber Pond (Pond #9)
• Closure of the Huntington Plant Coal Yard Storm Water Retention Pond
(Pond #10)
• Closure of the Huntington Plant Rock Garden Storm Water Pond (Pond #11)
• On-going remediation project (groundwater recovery and treatment) at the Huntington Plant Scrubber Pond (#9)
• Upper Demineralizer Pump Valve Pit (Ref. #24)
• Coal Yard Lube Oil Storage area (Ref. #36)
• Sewage Receiving Pit (Ref. #48)
• Fuel Oil Tanks area (Ref. #87)
• Fuel Dispensing Area (Ref. #88)
Potential Cost Savings
The active PacifiCorp-Huntington Industrial Waste Class IIIb Landfill can accept
plant generated wastes including paper products, plastic and metal drums, dirt,
wood products, lunch room wastes, scrap metal, drained filters, and digested
domestic wastewater treatment plant sludge. The current available storage
capacity should be evaluated so the landfill can be utilized to reduce disposal
costs during the decommissioning/demolition activities. The current Industrial
Waste Class IIIb landfill permit may require a permit modification to cover the
acceptance of some of decommissioning/demolition wastes.
The development of a site-wide final grading plan is recommended. The final
grading plan would evaluate cut-and-fill opportunities on the property to provide
soil cover materials to reduce the material costs for the cap-and-closure of the
existing landfills.
Site Controls
The site will be remediated to VCP determined industrial cleanup standards
which will be protective for an industrial use exposure scenario. Site controls will
be developed on an as needed basis following soil sampling in potential
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impacted areas. The foundation slabs will be left in place, providing an
engineered control to limit exposure. Final site grading will be designed to
mitigate erosion issues and reduce long-term maintenance costs. Long-term
monitoring and maintenance of the capped landfills will be estimated. Existing
site controls, such as security fencing, will be left in place and maintenance costs
estimated.
Site Monitoring and Access Controls
Site monitoring needs are unknown at this time and will be based on the
requirements of completed remediation projects. Access control during
remediation activities and post-closure monitoring will be included as a line item
cost.
3.4.6 Assumptions
(Reserved Pending Client Discussion)

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Attachment 1 – Facility Site Plans

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mile
km
1
2
Jim Bridger Plant Aerial View
feet
meters
2000
800
Dave Johnston Plant Aerial View
feet
meters
1000
400
Currant Creek Aerial View
N
PL
A
N
T
feet
km
3000
1
Huntington Plant Aerial View
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Attachment 2 – Permit Data
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APS - Four Corners
Decommissioning Permit Matrix
Permits/Notification Authority/Division Time Requirement Reason Required Requirements / Comment
Anticipated
Submittal Date/
Approval Date
Status
NPDES Federal/EPA Region 9 - Water Division Submitted at least 10 days
prior.
Formal Notification to EPA Notify EPA Region 8 of shutdown, documenting when the units go out of service and reduction of discharge/wastewater volume decreases.
This is also required for any chancges in topography that alters storm water flow from property.
Construction General Permit (CGP)EPA/Stormwater Complete NOI prior to
commencing construction
activities.
activities that disturb one or more acres smaller sites that are part of a larger common plan of development or sale, are regulated under the National Pollutant Discharge Elimination
System (NPDES) stormwater program. Prior to discharging stormwater, construction operators must obtain coverage under an NPDES permit,
which is administered by either the state (if it has been authorized to operate the NPDES stormwater program) or EPA, depending on where
the construction site is located.
To be covered under this permit, you must submit to EPA a complete and accurate NOI prior to commencing construction activities. You are
Storm Water Permit (Construction/Demolition)
the near future. If the drainage plan changes, then we will need to evaluate the impact and proceed from there. NOTE - SWPP must be
NA NA
Demolition Plan
notification. After speaking with State, they suggested the Demolition Plan be submitted by the middle of December (estimated date of
Fugitive Dust Control Plan Identify in Demolition Plan
Asbestos Notification
to beginning of activities
Lead Based Paint Notification Identify any lead based paint hazards Should be identify in Demolition Plan
As needed
containing radioactive material.radioactive material. Essentially, the gauges need to be taken out of service, and either stored on site or disposed of, before we notify the NRC
of their new location.
If applicable, submit Certificate of Disposition of Materials (NRC Form 314) to:
Material Radiation Protection Section
U.S. Nuclear Regulatory Commission, Region IV
1600 E. Lamar Boulevard
As needed
occupied spaces, foundations and supports. demolished. Construction permit checklists and permit applications (electrical, plumbing, mechanical) are available on the County Building
Division website.
Building permits may be required by the City of Farmington as well, but details should be discussed with the Permit Technicians.
UST 30 days and 24-hour
temporary closure, return to service or change in-service.
For UST system closures, owners and operators shall notify PSTB to allow an opportunity for an inspector to be present during steps (critical
junctures) or procedures which are important to the prevention of releases. Additionally, owners and operators are required to give a 24-hour
notice before any critical juncture begins.
The State requires the owner to Notify the State UST Program within 30 days of any change in the use of an underground storage tank.
Waterfowl Hazing and Collection
contributing to the need requirement. If ash
ponds are closed and evaporated, collection of
water fowl is no longer required.
Service.
contributing to the need requirement. If ash
ponds are closed and evaporated, collection of
water fowl is no longer required.
Service.
Hauling Permits
structure with height in excess of 200 feet construction, renovations, or demolition or temporary structures (construction cranes). 14 CFR 77.13
Septic Tank and Drain Field Application for a liquid waste permit or registration for a new permit or modification to an existing system.
Historic Buildings
prehistoric sites throughout the State.
Meet the state and federal laws that provide protection for historical and prehistorical properties.
Utility Clearance
construction activities
involving utilities. Permit
demolition activities authorization by the Department to Engineer and Design specific utility relocations on a highway construction project. More definitive
information on the permit requirements is available in 17.4.2 NMAC. Review of the permit normally takes up to 40 works days.
Within thirty (30) days of completion of the project, a set of hard copy as – built plans, stamped by a State Registered Land Surveyor are to be
submitted to this office by the utility owner.