P:\PACIFICORP\370414BART2\TECHNICAL_MEMORANDUM_DELIVERABLES\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 1 

TECHNICAL MEMORANDUM 

Addendum to Jim Bridger Unit 2 BART Report 

PREPARED FOR: Wyoming Division of Air Quality 

PREPARED BY: CH2M HILL 

COPIES: Bill Lawson/PacifiCorp 

DATE: March 26, 2008 

Introduction 

In compliance with the Regional Haze Rule (40 Code of Federal Regulations [CFR] 51), the 

Wyoming Division of Air Quality (WDAQ) required PacifiCorp Energy to conduct a detailed 

Best Available Retrofit Technology (BART) review to analyze the effects to visibility in nearby 

Class I areas from plant emissions, both for baseline and for reasonable control technology 

scenarios. PacifiCorp submitted these evaluations to WDAQ in January 2007. A revised report 

was submitted in October 2007. 

On January 3, 2008, PacifiCorp Energy personnel met with WDAQ staff to discuss the status of 

the BART reviews. At that time, the state requested that additional modeling scenarios for 

several of the PacifiCorp facilities be performed to aid in their BART review. This memorandum 

presents the economics analysis for two scenarios modeled, referred to as Scenario A and 

Scenario B and described as follows: 

• Scenario A: PacifiCorp committed controls at permitted rates—low nitrogen oxide (NOx) 

burners (LNBs) with over-fire air (OFA), sodium based flue gas desulfurization (FGD), 

SO3 injection 

• Scenario B: PacifiCorp committed controls and selective catalytic reduction (SCR) at 

permitted rates 

The CALPUFF modeling system (v. 5.711a) was used for this analysis. All technical options and 

model triggers used in CALMET, CALPUFF, and CALPOST are consistent with those used for 

the previous BART analyses and described in the BART report submitted in October 2007. 

Stack Parameters, Emissions Information, and Capital Cost 

Table 1 summarizes the control equipment for Scenarios A and B as well as the current 

equipment installed at the plant. The overall capital cost of installing these options is also shown. 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 2 

TABLE 1 

Control Scenario Summary 

Jim Bridger Unit 2 

 Equipment Type Capital Cost 

 NOx SO2 PM10

 Million 

dollars 

Baseline LNB with OFA Wet sodium FGD ESP — 

Scenario A LNB with OFA Wet sodium FGD ESP with SO3 injection $29.2 

Scenario B LNB with OFA and SCR Wet sodium FGD ESP with SO3 injection $195.7 

Emissions were modeled for the following pollutants: 

• Sulfur dioxide (SO2) 

• NOx

• Coarse particulate (PM2.5<diameter<PM10) 

• Fine particulate (diameter<PM2.5) 

• Sulfates 

Table 2 shows stack parameters and emission rates that were used for the Jim Bridger Unit 2 

BART modeling and analysis. 

TABLE 2 

Calpuff Model Inputs 

Jim Bridger Unit 2 

 BART Comparison(d)

Model Input Data Baseline 

Scenario 

A (e)

Scenario 

B (f)

Hourly Heat Input (mmBtu/hour) 6,000 6,000 6,000 

Sulfur Dioxide (SO2) Stack Emissions (lb/hr) 1,602 900 900 

Nitrogen Oxide (NOx) Stack Emissions (lb/hr) 1,440 1,560 420 

PM10 Stack Emissions (lb/hr) 444 180.0 180.0 

Coarse Particulate (PM2.5 <diameter< PM10) Stack Emissions (lb/hr)(a) 191 77.4 77.4 

Fine Particulate (diameter<PM2.5) Stack Emissions (lb/hr)(b) 253 102.6 102.6 

Sulfuric Acid (H2SO4) Stack Emissions (lb/hr) 55.2 55.2 94.7 

Ammonium Sulfate [(NH4)2SO4] Stack Emissions (lb/hr) — — 7.0 

(NH4)HSO4 Stack Emissions (lb/hr) — — 12.2 

H2SO4 as Sulfate (SO4) Stack Emissions (lb/hr) 54.1 54.1 92.8 

(NH4)2SO4 as SO4 Stack Emissions (lb/hr) — — 5.1 

(NH4)HSO4 as SO4 Stack Emissions (lb/hr) — — 10.2 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 3 

TABLE 2 

Calpuff Model Inputs 

Jim Bridger Unit 2 

 BART Comparison(d)

Model Input Data Baseline 

Scenario 

A (e)

Scenario 

B (f)

Total Sulfate (SO4) (lb/hr)(c) 54.1 54.1 108.1 

Stack Conditions 

Stack Height (meters) 152 152 152 

Stack Exit Diameter (meters) 7.32 7.32 7.32 

Stack Exit Temperature (Kelvin) 333 328 328 

Stack Exit Velocity (meters per second) 27.4 24.7 24.7 

NOTES:

(a) Based on AP-42, Table 1.1-6, the coarse particulates are counted as a percentage of PM10. This equates to 43% 

ESP and 57% Baghouse. PM10 and PM2.5 refer to particulate matter less than 10 and 2.5 micrometers, respectively, 

in aerodynamic diameter. 

(b) Based on AP-42, Table 1.1-6, the fine particulates are counted as a percentage of PM10. This equates to 57% 

ESP and 43% Baghouse. 

(c) Total Sulfate (SO4) (lb/hr) = H2SO4 as Sulfate (SO4) Stack Emissions (lb/hr) + (NH4)2SO4 as SO4 Stack Emissions 

(lb/hr) + (NH4)HSO4 as SO4 Stack Emissions (lb/hr) (d) SO2, NOx, and PM rates are expressed in terms of permitted emission rates. Actual emissions will be less than 

the permitted rates. 

(e) PacifiCorp Committed Controls @ permitted rates: LNB with OFA, Wet FGD, ESP with SO3 (f) PacifiCorp Committed Controls and SCR @ permitted rates

Economic Analysis 

In completing this additional analysis to supplement the previous BART study, technology 

alternatives were investigated and potential reductions in NOx, SO2, and PM10 emissions rates 

were identified. 

A comparison of Scenarios A and B on the basis of costs, design control efficiencies, and tons of 

pollutant removed is summarized in Tables 3 through 5. Capital costs were provided by 

PacifiCorp. The complete economic analyses for these two scenarios are provided as 

Attachment 1.
ADDENDUM T

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 

TABLE 3 Scenario A Control Cost Jim Bridger Unit 2 

 NOx Control SO2 Control PM10 Control 

Existing LNB with 

OFA Wet FGD 

ESP with Gas 

Conditioning 

Total Installed Capital Costs (million dollars) — $25.3 $3.90 

Annualized First-Year Capital Costs — $2.41 $0.37 

First Year Fixed & Variable O&M Costs (million dollars) — $0.98 $0.18 Total First Year Annualized Costs (million dollars) (a) — $3.39 $0.55 

Power Consumption (MW) — 0.53 0.05 

Annual Power Usage (Million kWh/Yr) — 4.18 0.39 Permitted Emission Rate (lb/mmBtu) 0.26 0.15 0.03 

Additional Tons of Pollutant Removed per Year over Baseline — 2,838 1,041 

First Year Average Control Cost ($/Ton of Pollutant Removed) — 1,194 525 

NOTE:

(a) First year annualized costs include power consumption costs. 
ADDENDUM T

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 

TABLE 4 Scenario B Control Cost Jim Bridger Unit 2 

 NOx Control SO2 Control PM10 Control 

LNB with OFA & 

SCR Wet FGD 

ESP with Gas 

Conditioning 

Total Installed Capital Costs (million dollars) $166.5 $25.3 $3.90 

Annualized First-Year Capital Costs $15.84 $2.41 $0.37 First Year Fixed & Variable O&M Costs (million dollars) $3.37 $0.98 $0.18 

Total First Year Annualized Costs (million dollars) (a) $19.21 $3.39 $0.55 

Power Consumption (MW) 3.25 0.53 0.05 

Annual Power Usage (Million kWh/Yr) 25.65 4.18 0.39 

Permitted Emission Rate (lb/mmBtu) 0.07 0.15 0.03 

Additional Tons of Pollutant Removed per Year over Baseline 4.494 2.838 1.041 

First Year Average Control Cost ($/Ton of Pollutant Removed) 4.275 1.194 525 NOTE:

(a) First year annualized costs include power consumption costs. 
ADDENDUM T

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 

TABLE 5 Incremental Control Costs, Scenario B compared to Scenario A Jim Bridger Unit 2 

 NOx Control SO2 Control PM10 Cont

Incremental Installed Capital Costs (million dollars) $166.5 0 0 

Incremental Annualized First-Year Capital Costs $15.84 0 0 

Incremental First Year Fixed & Variable O&M Costs (million dollars) $3.37 0 0 

Incremental First Year Annualized Costs (million dollars) (a) $19.21 0 0 

Incremental Power Consumption (MW) 3.25 0 0 

Incremental Annual Power Usage (Million kWh/Yr) 25.62 0 0 

Incremental Improvement in Emission Rate (lb/mmBtu) 0.19 0 0 Incremental Tons of Pollutant Removed 4,494 0 0 

Incremental First Year Average Control Cost ($/Ton of Pollutant Removed) 

4,275 0 0 

NOTE:

(a)Incremental first year annualized costs include power consumption costs. 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 7 

Modeling Results and Least-Cost Envelope Analysis 

CH2M HILL modeled Jim Bridger Unit 2 for two post-control scenarios. The results 

determine the change in deciview based on each alternative at the Class I areas specific to the 

project. The Class I areas potentially affected are Bridger Wilderness, Fitzpatrick Wilderness, 

and Mount Zirkel Wilderness for this unit. 

Modeled Scenarios 

Current operations (baseline) and two alternative control scenarios were modeled to cover the 

range of effectiveness for the combination of the individual NOx, SO2, and PM control 

technologies being evaluated. The modeled scenarios include the following: 

• Baseline: Current operations with LNB, Wet sodium FGD, and ESP 

• Scenario A: LNB with OFA, Wet sodium FGD, and ESP with SO3 injection 

• Scenario B: Scenario A with SCR 

Summary of Visibility Analysis 

Tables 6 through 8 present a summary of the modeling period (2001–2003) results for each 

scenario and Class I area. 

TABLE 6 

Costs and Visibility Modeling Results as Applicable to Bridger Wilderness 

Jim Bridger Unit 2 

Scenario Controls 

Total First Year 

Annualized 

Cost Highest ΔdV 

98th 

Percentile 

ΔdV 

Maximum 

Annual 

Number of 

Days Above 

0.5 dV 

Baseline Current Operations with FGD 

and ESP 

— 3.074 0.935 23 

Scenario A Scenario A: PacifiCorp 

Committed Controls 

$3,936,700 2.919 0.829 17 

Scenario B Scenario B: PacifiCorp 

Committed Controls and SCR 

$23,145,945 1.647 0.481 10 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 8 

TABLE 7 

Costs and Visibility Modeling Results as Applicable to Fitzpatrick Wilderness 

Jim Bridger Unit 2 

Scenario Controls 

Total First Year 

Annualized 

Cost Highest ΔdV 

98th 

Percentile 

ΔdV 

Maximum 

Annual 

Number of 

Days Above 

0.5 dV 

Baseline Current Operations with FGD 

and ESP 

— 1.666 0.434 9 

Scenario A Scenario A: PacifiCorp 

Committed Controls 

$3,936,700 1.747 0.379 7 

Scenario B Scenario B: PacifiCorp 

Committed Controls and SCR 

$23,145,945 0.959 0.232 4 

TABLE 8 

Costs and Visibility Modeling Results as Applicable to Mount Zirkel Wilderness 

Jim Bridger Unit 2 

Scenario Controls 

Total First Year 

Annualized 

Cost 

Highest 

ΔdV 

98th 

Percentile 

ΔdV 

Maximum 

Annual 

Number of 

Days Above 

0.5 dV 

Baseline Current Operations with FGD 

and ESP 

— 2.475 1.154 25 

Scenario A Scenario A: PacifiCorp 

Committed Controls 

$3,936,700 2.168 1.046 22 

Scenario B Scenario B: PacifiCorp 

Committed Controls and SCR 

$23,145,945 1.298 0.607 12 

Results 

Tables 9 through 11 present a summary of the costs and modeling results for each scenario 

and Class I area. 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 9 

TABLE 9 

Incremental Costs and Incremental Visibility Improvements Relative to Bridger Wilderness 

Jim Bridger Unit 2 

Scenario 

Comparison Controls 

Incremental 

Annualized 

Cost 

(Million$) 

Reduction 

in 98th 

Percentile 

maximum 

dV 

Reduction 

in Number 

of Days 

Above 

0.5 dV 

Cost per dV 

Reduction 

(Million$/dV 

Reduced) 

Cost per Day 

to Achieve a 

Reduction in 

the Days 

above 0.5 dV 

(Million$/Day) 

Scenario A 

Compared to 

Baseline 

Scenario A: 

PacifiCorp 

Committed 

Controls 

$3.94 0.106 6 $37.14 $0.66 

Scenario B 

Compared to 

Baseline 

Scenario B: 

PacifiCorp 

Committed 

Controls and SCR 

$23.15 0.454 13 $50.98 $1.78 

Scenario B 

Compared To 

Scenario A 

Addition of SCR $19.21 0.348 7 $55.20 $2.74 

TABLE 10 

Incremental Costs and Incremental Visibility Improvements Relative to Fitzpatrick Wilderness 

Jim Bridger Unit 2 

Scenario 

Comparison Controls 

Incremental 

Annualized 

Cost 

(Million$) 

Reduction 

in 98th 

Percentile 

maximum 

dV 

Reduction 

in Number 

of Days 

Above 

0.5 dV 

Cost per dV 

Reduction 

(Million$/dV 

Reduced) 

Cost per Day 

to Achieve a 

Reduction in 

the Days 

above 0.5 dV 

(Million$/Day) 

Scenario A 

Compared to 

Baseline 

Scenario A: 

PacifiCorp 

Committed 

Controls 

$3.94 0.055 2 $71.58 $1.97 

Scenario B 

Compared to 

Baseline 

Scenario B: 

PacifiCorp 

Committed 

Controls and SCR 

$23.15 0.202 5 $114.58 $4.63 

Scenario B 

Compared To 

Scenario A 

Addition of SCR $19.21 0.147 3 $130.68 $6.40 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 10 

TABLE 11 

Incremental Costs and Incremental Visibility Improvements Relative to Mount Zirkel Wilderness 

Jim Bridger Unit 2 

Scenario 

Comparison Controls 

Incremental 

Annualized 

Cost 

(Million$) 

Reduction 

in 98th 

Percentile 

maximum 

dV 

Reduction 

in Number 

of Days 

Above 

0.5 dV 

Cost per dV 

Reduction 

(Million$/dV 

Reduced) 

Cost per Day 

to Achieve a 

Reduction in 

the Days 

above 0.5 dV 

(Million$/Day) 

Scenario A 

Compared to 

Baseline 

Scenario A: 

PacifiCorp 

Committed 

Controls 

$3.94 0.108 3 $36.45 $1.31 

Scenario B 

Compared to 

Baseline 

Scenario B: 

PacifiCorp 

Committed 

Controls and SCR 

$23.15 0.547 13 $42.31 $1.78 

Scenario B 

Compared To 

Scenario A 

Addition of SCR $19.21 0.439 10 $43.76 $1.92 

Least-Cost Envelope Analysis 

The least-cost envelope graphs for Bridger Wilderness are shown in Figures 1 and 2, for 

Fitzpatrick Wilderness in Figures 3 and 4, and for Mount Zirkel Wilderness in 

Figures 5 and 6. 
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 11 

FIGURE 1 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Bridger Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0 2 4 6 8 10 12 14

Reduction in Days of Exceeding 0.5 dV (days)

Total Annualized Cost (Mil $)

FIGURE 2 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Bridger Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 0.45 0.50

98th Percentile Delta-Deciview Reduction (dV)

Total Annualized Cost (Mil $)
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 12 

FIGURE 3 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Fitzpatrick Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0123456

Reduction in Days of Exceeding 0.5 dV (days)

Total Annualized Cost (Mil $)

FIGURE 4 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Fitzpatrick Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0.00 0.05 0.10 0.15 0.20 0.25

98th Percentile Delta-Deciview Reduction (dV)

Total Annualized Cost (Mil $)
ADDENDUM TO JIM BRIDGER UNIT 2 BART REPORT 

JMS ES032008003SLC\BART_TMS_JIMBRIDGERUNIT2_FINAL.DOC 13 

FIGURE 5 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Mount Zirkel Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0 2 4 6 810 12 14

Reduction in Days of Exceeding 0.5 dV (days)

Total Annualized Cost (Mil $)

FIGURE 6 

Least Cost Envelope

 PacifiCorp Jim Bridger Unit 2 - Mount Zirkel Wilderness

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

0 2 4 6 8 10 12 14

98th Percentile Delta-Deciview Reduction (dV)

Total Annualized Cost (Mil $)
ATTACHMENT 1 

Complete Economic Analyses 

for Scenarios A and B 
ECONOMIC ANALYSIS SUMMARY - FIRST YEAR COSTS

Jim Bridger 2 Boiler Design: Tangential-Fired PC

TYPE OF EMISSIONS CONTROLS NOx Control 

Technology Label BASE A B C D 

Current Operation Low NOx Burners with Overfire Air Rotating Overfire Air

Low NOx Burners with 

Overfire Air and NonSelective Catalytic 

Reduction

Low NOx Burners 

Overfire Air an

Selective Catal

Reduction

ECONOMIC FACTORS

Interest Rate (%) 7.10% 7.10% 7.10% 7.10% 7.Discount Rate (%) 7.10% 7.10% 7.10% 7.10% 7.Plant Economic Life (Years) 20 20 20 20 

CAPITAL INVESTMENT 

Total Installed Capital Costs ($) $0 $0 $20,528,122 $13,427,239 $166,500 FIRST YEAR DEBT SERVICE ($/Yr) $0 $0 $1,952,796 $1,277,304 $15,838

FIRST YEAR FIXED O&M Costs ($/Yr)

Operating Labor ($/Yr) $0 $0 $0 $0 Maintenance Material ($/Yr) $0 $0 $42,000 $123,000 $190Maintenance Labor ($/Yr) $0 $0 $63,000 $184,500 $285Administrative Labor ($/Yr) $0 $0 $0 $0  TOTAL FIRST YEAR FIXED O&M COST $0 $0 $105,000 $307,500 $475

FIRST YEAR VARIABLE O&M Costs ($/Yr)

Makeup Water Costs ($/Yr) $0 $0 $0 $0 Reagent Costs ($/Yr) $0 $0 $0 $89,411 $1,020SCR Catalyst / FF Bag Costs ($/Yr) $0 $0 $0 $0 $594Waste Disposal Costs ($/Yr) $0 $0 $0 $0 Electric Power Costs ($/Yr) $0 $0 $2,526,822 $208,926 $1,281 TOTAL FIRST YEAR VARIABLE O&M Costs ($/Yr) $0 $0 $2,526,822 $298,337 $2,895

SUMMARY OF FIRST YEAR COSTS ($/Yr)

First Year Debt Service ($/Yr) $0 $0 $1,952,796 $1,277,304 $15,838First Year Fixed O&M Costs ($/Yr) $0 $0 $105,000 $307,500 $475First Year Variable O&M Costs ($/Yr) $0 $0 $2,526,822 $298,337 $2,895Total First Year Costs ($/Yr) $0 $0 $4,584,618 $1,883,141 $19,209

CONTROL COST COMPARISONS

NOx Technology Comparison

Additional NOx Removed From Base Case (Tons/Yr) 0 0 946 946 4

First Year Average Control Cost ($/Ton NOx Removed) $0 #DIV/0! $4,846 $1,990 $4

Technology Case Comparison A-BASE B-A C-A 

Incremental NOx Removed (Tons/Yr) 0 0 946 946 4

Incremental Control Cost ($/Ton NOx Removed) $0 #DIV/0! $4,846 $1,990 $4

SO2 Technology Comparison 77.5% 

Additional SO2 Removed From Base Case (Tons/Yr) 0 

First Year Average Control Cost ($/Ton SO2 Removed) $0 

Technology Case Comparison Incremental SO2 Removed (Tons/Yr) 0 

Incremental Control Cost ($/Ton SO2 Removed) $0 

PM Technology Comparison 0.0%Additional PM Removed From Base Case (Tons/Yr) 0 

First Year Average Control Cost ($/Ton PM Removed) $0 Technology Case Comparison Incremental PM Removed (Tons/Yr) 0 Incremental Control Cost ($/Ton PM Removed) $0 

SCENARIO A AND B COMPARISONS

Additional NOx, SO2, & PM Removed From Base Case (Tons/Yr) 0 

First Year Average Control Cost Compared to Base Case ($/Ton Removed) $0 Incremental Tons Removed - Scenario B vs Scenario A (Tons/Yr) 0 Incremental Control Costs - Scenario B vs Scenario A ($/Ton Removed) $0 

JMS ES032008003SLC\First Yr Summary\JB2 appendix.xls 
INPUT CALCULATIONS

Jim Bridger 2 Boiler Design: Tangential-Fired PC

PARAMETER Current Operation NOx Control Technologies 

Control TechnologiesNOx Emission Control System LNB - TFS 2000 Existing LNB w/OFA ROFA LNB w/OFA & SNCR LNB w/OFA & SCR 

SO2 Emission Control System Wet FGD N/A 

PM Emission Control System ESP ESP w/ Gas Conditioning 

General Plant Design and Operating Data

Type of Unit PC PC PC PC PC PC Annual Power Plant Capacity Factor 90% 90% 90% 90% 90% 90% Annual Operation (Hours/Year) 7,884 7,884 7,884 7,884 7,884 7,88Net Power Output (kW) 530,000 530,000 530,000 530,000 530,000 530,00Net Plant Heat Rate (Btu/kW-Hr) 11,320 11,320 11,320 11,320 11,320 11,32Boiler Heat Input, Measured by Fuel Input (MMBtu/Hr) 6,000 6,000 6,000 6,000 6,000 6,00Annual Heat Input, Measured by Fuel Input (MMBtu/Year) 47,300,846 47,300,846 47,300,846 47,300,846 47,300,846 47,300,84Boiler Heat Input, Measured by CEM (MMBtu/Hr) 6,000 6,000 6,000 6,000 6,000 6,00Annual Heat Input, Measured by CEM (MMBtu/Year) 47,304,000 47,304,000 47,304,000 47,304,000 47,304,000 47,304,00

Plant Fuel Source

Boiler Fuel Source Bridger Mine Underground Bridger Mine Underground Bridger Mine Underground Bridger Mine Underground Bridger Mine Underground Bridger Mine Underground 

Coal Heating Value (Btu/Lb) 9,660 9,660 9,660 9,660 9,660 9,66Coal Sulfur Content (wt.%) 0.58% 0.58% 0.58% 0.58% 0.58% 0.58% Coal Ash Content (wt.%) 10.30% 10.30% 10.30% 10.30% 10.30% 10.30% Coal Flow Rate (Lb/Hr) 621,077 621,077 621,077 621,077 621,077 621,07Coal Consumed (Ton/Yr) 2,448,284 2,448,284 2,448,284 2,448,284 2,448,284 2,448,28

Nitrogen Oxide Emissions

NOx Emission Rate (Lb/MMBtu) 0.26 0.26 0.22 0.22 0.07 

NOx Emission Rate (Lb/Hr) 1,560 1,560 1,320 1,320 420 

NOx Emission Rate (Lb Moles/Hr) 51.98 51.98 43.99 43.99 14.00 NOx Emission Rate (Ton/Yr) 6,150 6,150 5,203 5,203 1,656 Add'l NOx Removed from Current Operations (Lb/Hr) 0 0 240 240 1,140 

Add'l NOx Removed from Current Operations (Ton/Yr) 0 0 946 946 4,494 

Sulfur Dioxide Emissions

Uncontrolled SO2 (Lb/MMBtu) 1.20 1.2

Uncontrolled SO2 (Lb/Hr) 7,198 7,19

Uncontrolled SO2 (Lb Moles/Hr) 112.35 112.3

Uncontrolled SO2 (Tons/Yr) 28,374 28,37Controlled SO2 Emission Rate (Lb/MMBtu) 0.27 0.2

SO2 Removal Efficiency (%) 77.5% 77.5% 

Controlled SO2 Emissions (Lb/Hr) 1,620 1,62

Controlled SO2 Emissions (Ton/Yr) 6,386 6,38

SO2 Removed (Lb/Hr) 5,578 5,57

SO2 Removed (Ton/Yr) 21,988 21,98

Add'l SO2 Removed from Current Operations (Lb/Hr) 0 

Add'l SO2 Removed from Current Operations (Ton/Yr) 0 

Particulate Matter Emissions

Uncontrolled Fly Ash (Lb/Hr) 51,177 51,17Uncontrolled Fly Ash (Lb/MMBtu) 8.529 8.52Uncontrolled Fly Ash (Tons/Yr) 201,739 201,73Controlled Fly Ash Emission Rate (Lb/MMBtu) 0.074 0.03Controlled Fly Ash Removal Efficiency (%) 99.1% 99.6% Controlled Fly Ash Emissions (Lb/Hr) 444 18Controlled Fly Ash Emissions (Ton/Yr) 1,750 71Fly Ash Removed (Lb/Hr) 50,733 50,99Fly Ash Removed (Ton/Yr) 199,988 201,02Add'l Ash Removed from Current Operation (Lb/Hr) 0 26Add'l Ash Removed from Current Operation (Ton/Yr) 0 1,04

Economic Factors

Interest Rate (%) 7.10% 7.10% 7.10% 7.10% 7.10% 7.10% Discount Rate (%) 7.10% 7.10% 7.10% 7.10% 7.10% 7.10% Plant Economic Life (Years) 20 20 20 20 20 2

SO2 and 

JMS ES032008003SLC\Tech Calcs\JB2 appendix.xls 
INPUT CALCULATIONS

Jim Bridger 2 Boiler Design: Tangential-Fired PC

PARAMETER Current Operation NOx Control Technologies 

Control TechnologiesNOx Emission Control System LNB - TFS 2000 Existing LNB w/OFA ROFA LNB w/OFA & SNCR LNB w/OFA & SCR 

SO2 Emission Control System Wet FGD N/A 

PM Emission Control System ESP ESP w/ Gas Conditioning 

SO2 and 

Installed Capital Costs

NOx Emission Control System ($2012) $0 $20,528,122 $13,427,239 $166,500,000 

SO2 Emission Control System ($2012) $

PM Emission Control System ($2012) $3,900,00Total Emission Control System Capital Costs ($2012) $0 $20,528,122 $13,427,239 $166,500,000 $3,900,00NOx Emission Control System ($/kW) $39 $25 $314 

SO2 Emission Control System ($/kW) 

PM Emission Control System ($/kW) $Total Emission Control Capital Costs ($/kW) $39 $25 $314 $

Fixed Operating & Maintenance Costs

Operating Labor ($) $0 $0 $0 $0 $Maintenance Material ($) $0 $42,000 $123,000 $190,000 $Maintenance Labor ($) $0 $63,000 $184,500 $285,000 $10,00Administrative Labor ($) $0 $0 $0 $0 $Total 1st Fixed Year O&M Cost ($) $0 $105,000 $307,500 $475,000 $10,00Annual Fixed O&M Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Fixed O&M Cost ($/Yr) $0 $124,478 $364,542 $563,114 $11,85

Variable Operating & Maintenance Costs

Water CostMakeup Water Usage (gpm) 0 0 0 0 Unit Price ($/1000 gallons) $1.22 $1.22 $1.22 $1.22 $1.2First Year Water Cost ($) $0 $0 $0 $0 $Annual Water Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Water Costs ($/Yr) $0 $0 $0 $0 $Reagent CostType of Reagent None None Urea Anhydrous NH3 Elemental Sulfur Unit Cost ($/Ton) $0.00 $370.00 $400.00 $370.0Unit Cost ($/Lb) $0.000 $0.185 $0.200 $0.18Molar Stoichiometry 0.00 0.45 1.00 0.0Reagent Purity (Wt.%) 100% 100% 100% 100% Reagent Usage (Lb/Hr) 61 647 10First Year Reagent Cost ($) $0 $89,411 $1,020,310 $145,85Annual Reagent Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% Levelized Reagent Costs ($/Yr) $105,997 $1,209,580 $172,91SCR Catalyst / Fabric Filter Bag Replacement CostMaterial Replaced SCR Catalyst Annual SCR Catalyst (m3) / No. FF Bags 198 SCR Catalyst ($/m3) / Bag Cost ($/ea.) $3,000 First Year SCR Catalyst / Bag Replacement Cost ($) $594,000 Annual SCR Catalyst / Bag Cost Escalation Rate (%) 2.00% Levelized Catalyst/Fabric Fitler Bag Costs ($/Yr) $704,189 FGD Waste Disposal CostFGD Solid Waste Disposal Rate, Dry (Lb/Hr) FGD Waste Disposal Unit Cost ($/Dry Ton) $24.3First Year FGD Waste Disposal Cost ($) $Annual Waste Disposal Cost Esc. Rate (%) 2.00% Levelized Waste Disposal Costs ($/Yr) $Auxiliary Power CostAuxiliary Power Requirement (MW) 0.00 6.41 0.53 3.25 0.0Auxiliary Power Requirement (% of Plant Output) 0.00% 1.21% 0.10% 0.61% 0.01% Auxilliary Power Useage (MWh) 0 50,536 4,179 25,623 39Unit Cost ($2006/MW-Hr) $50.00 $50.00 $50.00 $50.00 $50.0First Year Auxiliary Power Cost ($) $0 $2,526,822 $208,926 $1,281,150 $19,71Annual Power Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Auxilliary Power Costs ($/Yr) $0 $2,995,555 $247,682 $1,518,807 $23,36

JMS ES032008003SLC\Tech Calcs\JB2 appendix.xls