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

TECHNICAL MEMORANDUM 

Addendum to Wyodak 1 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. Although Wyodak 

was not one of the facilities that required re-modeling, this memorandum presents the economics 

analysis for two scenarios previously 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), dry flue gas desulfurization (FGD), new fabric 

filter 

• 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 WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 2 

TABLE 1 

Control Scenario Summary 

Wyodak Unit 1 

 Equipment Type Capital Cost 

 NOx SO2 PM10 Million dollars 

Baseline 

Good Engineering 

Practices Dry FGD ESP — 

Scenario A LNB with OFA Dry FGD Fabric Filter $93.9 

Scenario B LNB with OFA and SCR Dry FGD Fabric Filter $252.7 

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 Wyodak BART 

modeling and analysis. 

TABLE 2 

Calpuff Model Inputs 

Wyodak Unit 1 

 BART Comparison(d)

Model Input Data Baseline 

Scenario 

A (e) Scenario B (f)

Hourly Heat Input (mmBtu/hour) 4,700 4,700 4,700 

Sulfur Dioxide (SO2) Stack Emissions (lb/hr) 2,350 759 759 

Nitrogen Oxide (NOx) Stack Emissions (lb/hr) 1,457 1,081 329 

PM10 Stack Emissions (lb/hr) 141 70.5 70.5 

Coarse Particulate (PM2.5 <diameter< PM10) Stack Emissions (lb/hr)(a) 60.6 40.2 40.2 

Fine Particulate (diameter<PM2.5) Stack Emissions (lb/hr)(b) 80.4 30.3 30.3 

Sulfuric Acid (H2SO4) Stack Emissions (lb/hr) 5.6 5.6 9.4 

Ammonium Sulfate [(NH4)2SO4] Stack Emissions (lb/hr) — — 1.1 

(NH4)HSO4 Stack Emissions (lb/hr) — — 1.9 

H2SO4 as Sulfate (SO4) Stack Emissions (lb/hr) 5.5 5.5 9.2 

(NH4)2SO4 as SO4 Stack Emissions (lb/hr) — — 0.8 

(NH4)HSO4 as SO4 Stack Emissions (lb/hr) — — 1.6 
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 3 

TABLE 2 

Calpuff Model Inputs 

Wyodak Unit 1 

 BART Comparison(d)

Model Input Data Baseline 

Scenario 

A (e) Scenario B (f)

Total Sulfate (SO4) (lb/hr)(c) 5.5 5.5 11.6 

Stack Conditions 

Stack Height (meters) 122 122 122 

Stack Exit Diameter (meters) 6.1 6.1 6.1 

Stack Exit Temperature (Kelvin) 358 350 350 

Stack Exit Velocity (meters per second) 23.5 23.5 23.5 

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, Dry FGD, New Fabric Filter (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.
ADD

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 

TABLE 3 Scenario A Control Cost Wyodak Unit 1 

 NOx Control SO2 Control PM10 Control 

LNB with OFA Dry FGD Fabric Filter 

Total Installed Capital Costs (million dollars) $13.10 $80.80 — 

Annualized First-Year Capital Costs $1.25 $7.69 — First Year Fixed & Variable O&M Costs (million dollars) $0.06 $1.27 — Total First Year Annualized Costs (million dollars) (a) $1.31 $8.95 — 

Power Consumption (MW) — 0.15 — Annual Power Usage (Million kWh/Yr) — 11.834 — 

Permitted Emission Rate (lb/mmBtu) 0.23 0.16 0.015 

Additional Tons of Pollutant Removed per Year over Baseline 1,482 6,272 — 

First Year Average Control Cost ($/Ton of Pollutant Removed) 881 1,428 — 

NOTE:

(a) First year annualized costs include power consumption costs. 
ADD

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 

TABLE 4 Scenario B Control Cost Wyodak Unit 1 

 NOx Control SO2 Control PM10 Control 

LNB with OFA & 

SCR Dry FGD Fabric Filter 

Total Installed Capital Costs (million dollars) $171.90 $80.80 — 

Annualized First-Year Capital Costs $16.35 $7.69 — 

First Year Fixed & Variable O&M Costs (million dollars) $2.56 $1.27 — 

Total First Year Annualized Costs (million dollars) (a) $18.91 $8.95 — 

Power Consumption (MW) 2.42 0.15 — 

Annual Power Usage (Million kWh/Yr) 19.05 1.18 — Permitted Emission Rate (lb/mmBtu) 0.07 0.16 0.015 

Additional Tons of Pollutant Removed per Year over Baseline 4,447 6,272 278 

First Year Average Control Cost ($/Ton of Pollutant Removed) 4,253 1,428 — NOTE:

(a) First year annualized costs include power consumption costs. 
ADD

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 

TABLE 5 Incremental Control Costs, Scenario B compared to Scenario A Wyodak Unit 1 

 NOx Control SO2 Control PM10 Control 

Incremental Installed Capital Costs (million dollars) $158.8 — — 

Incremental Annualized First-Year Capital Costs $15.11 — — 

Incremental First Year Fixed & Variable O&M Costs (million dollars) $2.50 — — 

Incremental First Year Annualized Costs (million dollars) (a) $17.60 — — 

Incremental Power Consumption (MW) 2.42 — — 

Incremental Annual Power Usage (Million kWh/Yr) 19.05 — — 

Incremental Improvement in Emission Rate (lb/mmBtu) 0.23 — — 

Incremental Tons of Pollutant Removed 2,964 — — 

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

5,939 — — 

NOTE:

(a)Incremental first year annualized costs include power consumption costs. 
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 7 

Modeling Results and Least-Cost Envelope Analysis 

CH2M HILL modeled Wyodak 1 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 Badlands National Park and Wind Cave National Park 

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 Good Engineering Practices, Dry FGD, and ESP 

• Scenario A: LNB with OFA, Dry FGD, and Fabric Filter 

• Scenario B: Scenario A with SCR 

Summary of Visibility Analysis 

Tables 6 and 7 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 Badlands National Park 

Wyodak Unit 1 

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 

— 2.556 1.065 34 

Scenario A Scenario A: PacifiCorp 

Committed Controls 

$10,260,225 1.319 0.554 14 

Scenario B Scenario B: PacifiCorp 

Committed Controls and SCR 

$27,864,456 0.811 0.308 2 
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 8 

TABLE 7 

Costs and Visibility Modeling Results as Applicable to Wind Cave National Park 

Wyodak Unit 1 

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 

— 3.296 1.353 41 

Scenario A Scenario A: PacifiCorp 

Committed Controls 

$10,260,225 1.797 0.751 17 

Scenario B Scenario B: PacifiCorp 

Committed Controls and SCR 

$27,864,456 1.065 0.389 6 

Results 

Tables 8 and 9 present a summary of the costs and modeling results for each scenario and 

Class I area. 

TABLE 8 

Incremental Costs and Incremental Visibility Improvements Relative to Badlands National Park 

Wyodak Unit 1 

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 

$10.26 0.511 20 $20.08 $0.51 

Scenario B 

Compared to 

Baseline 

Scenario B: 

PacifiCorp 

Committed 

Controls and SCR 

$27.86 0.757 32 $36.81 $0.87 

Scenario B 

Compared To 

Scenario A 

Addition of SCR $17.60 0.246 12 $71.56 $1.47 
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 9 

TABLE 9 

Incremental Costs and Incremental Visibility Improvements Relative to Wind Cave National Park 

Wyodak Unit 1 

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 

$10.26 0.602 24 $17.04 $0.43 

Scenario B 

Compared to 

Baseline 

Scenario B: 

PacifiCorp 

Committed Controls 

and SCR 

$27.86 0.964 35 $28.91 $0.80 

Scenario B 

Compared To 

Scenario A 

Addition of SCR $17.60 0.362 11 $48.63 $1.60 

Least-Cost Envelope Analysis 

The least-cost envelope graphs for Badlands National Park are shown in Figures 1 and 2 and 

for Wind Cave National Park are shown in Figures 3 and 4. 
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 10 

FIGURE 1 

Least Cost Envelope

 PacifiCorp Wyodak Unit 1 - Badlands National Park

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

$30.0

0 5 10 15 20 25 30 35

Reduction in Days of Exceeding 0.5 dV (days)

Total Annualized Cost (Mil $)

FIGURE 2 

Least Cost Envelope

 PacifiCorp Wyodak Unit 1 - Badlands National Park

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

$30.0

0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80

98th Percentile Delta-Deciview Reduction (dV)

Total Annualized Cost (Mil $)
ADDENDUM TO WYODAK 1 BART REPORT 

JMS ES032008003SLC\BART_TMS_WYODAK_FINAL.DOC 11 

FIGURE 3 

Least Cost Envelope

 PacifiCorp Wyodak Unit 1 - Wind Cave National Park

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

$30.0

0 5 10 15 20 25 30 35 40

Reduction in Days of Exceeding 0.5 dV (days)

Total Annualized Cost (Mil $)

FIGURE 4 

Least Cost Envelope

 PacifiCorp Wyodak Unit 1 - Wind Cave National Park

Scenario B

Scenario A

Baseline

$0.0

$5.0

$10.0

$15.0

$20.0

$25.0

$30.0

0.00 0.20 0.40 0.60 0.80 1.00 1.20

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

Wyodak Boiler Design: Opposed Wall-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 with 

Overfire Air and 

Selective Catalytic 

Reduction

U

CAPITAL INVESTMENT 

Total Installed Capital Costs ($) $0 $13,100,000 $15,252,149 $19,495,654 $171,900,000  FIRST YEAR DEBT SERVICE ($/Yr) $0 $1,246,174 $1,450,904 $1,854,579 $16,352,473 

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

Operating Labor ($/Yr) $0 $0 $0 $0 $0 Maintenance Material ($/Yr) $0 $24,000 $36,000 $93,000 $181,000 Maintenance Labor ($/Yr) $0 $36,000 $54,000 $139,500 $271,500 Administrative Labor ($/Yr) $0 $0 $0 $0 $0  TOTAL FIRST YEAR FIXED O&M COST $0 $60,000 $90,000 $232,500 $452,500 

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

Makeup Water Costs ($/Yr) $0 $0 $0 $0 $0 Reagent Costs ($/Yr) $0 $0 $0 $87,549 $673,047 SCR Catalyst / FF Bag Costs ($/Yr) $0 $0 $0 $0 $480,000 Waste Disposal Costs ($/Yr) $0 $0 $0 $0 $0 Electric Power Costs ($/Yr) $0 $0 $2,057,685 $132,057 $952,387  TOTAL FIRST YEAR VARIABLE O&M Costs ($/Yr) $0 $0 $2,057,685 $219,606 $2,105,434 

SUMMARY OF FIRST YEAR COSTS ($/Yr)

First Year Debt Service ($/Yr) $0 $1,246,174 $1,450,904 $1,854,579 $16,352,473 First Year Fixed O&M Costs ($/Yr) $0 $60,000 $90,000 $232,500 $452,500 First Year Variable O&M Costs ($/Yr) $0 $0 $2,057,685 $219,606 $2,105,434 

Total First Year Costs ($/Yr) $0 $1,306,174 $3,598,588 $2,306,685 $18,910,407 

CONTROL COST COMPARISONS

NOx Technology Comparison

Additional NOx Removed From Base Case (Tons/Yr) 0 1,482 2,038 2,409 4,447

First Year Average Control Cost ($/Ton NOx Removed) $0 $881 $1,766 $958 $4,253

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

Incremental NOx Removed (Tons/Yr) 0 1,482 556 926 2,964

Incremental Control Cost ($/Ton NOx Removed) $0 $881 $4,124 $1,080 $5,939

SO2 Technology Comparison 69.0% 

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\Wyodak appendix.xls 
INPUT CALCULATIONS

Wyodak Boiler Design: Opposed Wall-Fired PC

PARAMETER Current Operation NOx Control Technologies 

Control TechnologiesNOx Emission Control System Good Practices LNB w/OFA ROFA LNB w/OFA & SNCR LNB w/OFA & SCR 

SO2 Emission Control System Dry FGD Upgraded Dry FGD 

PM Emission Control System ESP 

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) 335,000 335,000 335,000 335,000 335,000 335,00Net Plant Heat Rate (Btu/kW-Hr) 12,087 12,087 12,087 12,087 12,087 12,08Boiler Heat Input, Measured by Fuel Input (MMBtu/Hr) 4,049 4,049 4,049 4,049 4,049 4,04Annual Heat Input, Measured by Fuel Input (MMBtu/Year) 31,923,459 31,923,459 31,923,459 31,923,459 31,923,459 31,923,45Boiler Heat Input, Measured by CEM (MMBtu/Hr) 4,700 4,700 4,700 4,700 4,700 4,70Annual Heat Input, Measured by CEM (MMBtu/Year) 37,054,800 37,054,800 37,054,800 37,054,800 37,054,800 37,054,80

Plant Fuel Source

Boiler Fuel Source Clovis Point Mine Clovis Point Mine Clovis Point Mine Clovis Point Mine Clovis Point Mine Clovis Point Mine Coal Heating Value (Btu/Lb) 8,050 8,050 8,050 8,050 8,050 8,05Coal Sulfur Content (wt.%) 0.65% 0.65% 0.65% 0.65% 0.65% 0.65% Coal Ash Content (wt.%) 7.46% 7.46% 7.46% 7.46% 7.46% 7.46% Coal Flow Rate (Lb/Hr) 502,999 502,999 502,999 502,999 502,999 502,99Coal Consumed (Ton/Yr) 1,982,824 1,982,824 1,982,824 1,982,824 1,982,824 1,982,82

Nitrogen Oxide Emissions

NOx Emission Rate (Lb/MMBtu) 0.31 0.23 0.20 0.18 0.07 

NOx Emission Rate (Lb/Hr) 1,457 1,081 940 846 329 

NOx Emission Rate (Lb Moles/Hr) 48.55 36.02 31.32 28.19 10.96 NOx Emission Rate (Ton/Yr) 5,743 4,261 3,705 3,335 1,297 Add'l NOx Removed from Current Operations (Lb/Hr) 0 376 517 611 1,128 

Add'l NOx Removed from Current Operations (Ton/Yr) 0 1,482 2,038 2,409 4,447 

Sulfur Dioxide Emissions

Uncontrolled SO2 (Lb/MMBtu) 1.61 1.6

Uncontrolled SO2 (Lb/Hr) 7,582 7,58

Uncontrolled SO2 (Lb Moles/Hr) 118.36 118.3

Uncontrolled SO2 (Tons/Yr) 29,890 29,89Controlled SO2 Emission Rate (Lb/MMBtu) 0.50 0.3

SO2 Removal Efficiency (%) 69.0% 80.0% 

Controlled SO2 Emissions (Lb/Hr) 2,350 1,51

Controlled SO2 Emissions (Ton/Yr) 9,264 5,98SO2 Removed (Lb/Hr) 5,232 6,06

SO2 Removed (Ton/Yr) 20,626 23,90

Add'l SO2 Removed from Current Operations (Lb/Hr) 0 83

Add'l SO2 Removed from Current Operations (Ton/Yr) 0 3,28

Particulate Matter Emissions

Uncontrolled Fly Ash (Lb/Hr) 30,019 30,01Uncontrolled Fly Ash (Lb/MMBtu) 6.387 6.38Uncontrolled Fly Ash (Tons/Yr) 118,335 118,33Controlled Fly Ash Emission Rate (Lb/MMBtu) 0.030 0.03Controlled Fly Ash Removal Efficiency (%) 99.5% 99.5% Controlled Fly Ash Emissions (Lb/Hr) 141 14Controlled Fly Ash Emissions (Ton/Yr) 556 55Fly Ash Removed (Lb/Hr) 29,878 29,87Fly Ash Removed (Ton/Yr) 117,779 117,77Add'l Ash Removed from Current Operation (Lb/Hr) 0 Add'l Ash Removed from Current Operation (Ton/Yr) 0 

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 

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

Wyodak Boiler Design: Opposed Wall-Fired PC

PARAMETER Current Operation NOx Control Technologies 

Control TechnologiesNOx Emission Control System Good Practices LNB w/OFA ROFA LNB w/OFA & SNCR LNB w/OFA & SCR 

SO2 Emission Control System Dry FGD Upgraded Dry FGD 

PM Emission Control System ESP 

SO2 

Installed Capital Costs

NOx Emission Control System ($2006) $13,100,000 $15,252,149 $19,495,654 $171,900,000 

SO2 Emission Control System ($2006) $26,759,01

PM Emission Control System ($2006) $Total Emission Control System Capital Costs ($2006) $13,100,000 $15,252,149 $19,495,654 $171,900,000 $26,759,01NOx Emission Control System ($/kW) $39 $46 $58 $513 

SO2 Emission Control System ($/kW) $8

PM Emission Control System ($/kW)Total Emission Control Capital Costs ($/kW) $39 $46 $58 $513 $8

Fixed Operating & Maintenance Costs

Operating Labor ($) $0 $0 $0 $0 $Maintenance Material ($) $24,000 $36,000 $93,000 $181,000 $21,90Maintenance Labor ($) $36,000 $54,000 $139,500 $271,500 $14,60Administrative Labor ($) $0 $0 $0 $0 $Total 1st Fixed Year O&M Cost ($) $60,000 $90,000 $232,500 $452,500 $36,50Annual Fixed O&M Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Fixed O&M Cost ($/Yr) $71,130 $106,695 $275,629 $536,440 $43,27

Variable Operating & Maintenance Costs

Water CostMakeup Water Usage (gpm) 0 0 0 0 2Unit Price ($/1000 gallons) $1.22 $1.22 $1.22 $1.22 $1.2First Year Water Cost ($) $0 $0 $0 $0 $14,38Annual Water Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Water Costs ($/Yr) $0 $0 $0 $0 $17,05Reagent CostType of Reagent None None Urea Anhydrous NH3 Lime Unit Cost ($/Ton) $0.00 $370.00 $400.00 $91.2Unit Cost ($/Lb) $0.000 $0.185 $0.200 $0.04Molar Stoichiometry 0.00 0.45 1.00 1.1Reagent Purity (Wt.%) 100% 100% 100% 90% Reagent Usage (Lb/Hr) 60 427 89First Year Reagent Cost ($) $0 $87,549 $673,047 $320,19Annual Reagent Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% Levelized Reagent Costs ($/Yr) $103,789 $797,899 $379,59SCR Catalyst / Fabric Filter Bag Replacement CostMaterial Replaced SCR Catalyst Annual SCR Catalyst (m3) / No. FF Bags 160 SCR Catalyst ($/m3) / Bag Cost ($/ea.) $3,000 First Year SCR Catalyst / Bag Replacement Cost ($) $480,000 Annual SCR Catalyst / Bag Cost Escalation Rate (%) 2.00% Levelized Catalyst/Fabric Fitler Bag Costs ($/Yr) $569,041 FGD Waste Disposal CostFGD Solid Waste Disposal Rate, Dry (Lb/Hr) 1,75FGD Waste Disposal Unit Cost ($/Dry Ton) $24.3First Year FGD Waste Disposal Cost ($) $167,95Annual Waste Disposal Cost Esc. Rate (%) 2.00% Levelized Waste Disposal Costs ($/Yr) $199,11Auxiliary Power CostAuxiliary Power Requirement (MW) 0.00 5.22 0.34 2.42 0.1Auxiliary Power Requirement (% of Plant Output) 0.00% 1.56% 0.10% 0.72% 0.03% Auxilliary Power Useage (MWh) 0 41,154 2,641 19,048 89Unit Cost ($2006/MW-Hr) $50.00 $50.00 $50.00 $50.00 $50.0First Year Auxiliary Power Cost ($) $0 $2,057,685 $132,057 $952,387 $44,93Annual Power Cost Escalation Rate (%) 2.00% 2.00% 2.00% 2.00% 2.00% Levelized Auxilliary Power Costs ($/Yr) $0 $2,439,391 $156,554 $1,129,058 $53,27

JMS ES032008003SLC\Tech Calcs\Wyodak appendix.xls