SCR AND ID FAN & AUXILIARY POWER 

CONCEPTUAL DESIGN COSTS 

CONCEPTUAL COST ESTIMATE 

PREPARED FOR 

NEBRASKA PUBLIC POWER DISTRICT 

GERALD GENTLEMAN STATION, UNITS 1&2 

Project No. 12194-001 

February 7, 2008 
Nebraska Public Power District 

General Gentleman Station, Units 1&2 

 Project No. 12194-001 

2/7/2008 

Table of Contents

BART Revised Capital and O&M Costs 

 ProForma 

Basis of Estimate 

Technical Basis 

Estimate Summary 

Estimates by Area: 

- Unit 1 SCR Area (Estimate No. 23288B) 

- Unit 2 SCR Area (Estimate No. 23296B) 

- Units 1&2 Common (Estimate No. 23297B) 

- Auxiliary Power and Booster ID Fans (Estimate No. 23298B) 

General Arrangement of SCR 

 Color 3-D General Arrangement of SCR (New Equipment in Teal)
Selective Catalytic Reduction

Capital and O&M Costs

GGS Unit 1 GGS Unit 2 Common Facilities Auxiliary Power/ID Fans TOTAL STATION

Capital Costs

SCR Area 2,316,000 $ 2,316,000 $ - $ - $ 4,632,0

$ 

Civil/SiteWork 710,000 $ 710,000 $ - $ - $ 1,420,0

$ 

Flue Gas System/Ductwork 37,022,000 $ 38,442,000 $ - $ - $ 75,464,0

$ 

Modifications 6,038,000 $ 6,038,000 $ - $ - $ 12,076,0

$ 

Catalyst 9,216,000 $ 9,216,000 $ - $ - $ 18,432,0

$ 

Common Structures/Buildings - $ - $ 1,185,000 $ - $ 1,185,0

$ 

Urea to AmmoniaSystem - $ - $ 11,232,000 $ - $ 11,232,0

$ 

Miscellaneous Mechanical Items 513,000 $ 678,000 $ 1,495,000 $ - $ 2,686,0

$ 

Pipe Rack 876,000 $ 876,000 $ - $ - $ 1,752,0

$ 

Booster Fans - $ - $ - $ 12,205,000 $ 12,205,0

$ 

Instrumentation and Controls - $ - $ 2,040,000 $ - $ 2,040,0

$ 

Allowance for Additonal Cranes - $ - $ 2,000,000 $ - $ 2,000,0

$ 

Electrical Modifications - $ - $ - $ 25,962,000 $ 25,962,0

$ 

Mobilization/Demobilization - 1% of Labor 294,000 $ 307,000 $ 65,000 $ 150,000 $ 816,0

$ 

Cost Due to Overtime - 5-10's 4,249,000 $ 4,365,000 $ 935,000 $ 2,244,000 $ 11,793,0

$ 

Per Diem 3,407,000 $ 2,864,000 $ 685,000 $ 2,610,000 $ 9,566,0

$ 

Spare Parts - 3% of Equipment 275,000 $ 275,000 $ 246,000 $ 536,000 $ 1,332,0

$ 

Freight 1,376,000 $ 1,394,000 $ 484,000 $ 1,157,000 $ 4,411,0

$ 

General & Administration - 5% of Material and Labor 2,574,000 $ 2,662,000 $ 432,000 $ 1,116,000 $ 6,784,0

$ 

Profit - 10% of Material and Labor 5,149,000 $ 5,323,000 $ 865,000 $ 2,232,000 $ 13,569,0

$ 

EPC Fee - 20% of Total Cost 14,803,000 $ 15,093,000 $ 9,304,000 $ 9,642,000 $ 48,842,0

$ 

Subtotal $ 90,559,000 88,818,000 $ 30,968,000 $ 57,854,000 $ 268,199,0

$ 

Other Costs

Indirect 1,776,000 $ 1,811,000 $ 30,468,000 $ 1,157,000 $ 35,212,0

$ 

Escalation 17,030,000 $ 18,492,000 $ 13,467,000 $ 11,493,000 $ 60,482,0

$ 

Sales/Use Tax 1,738,000 $ 1,763,000 $ 679,000 $ 1,409,000 $ 5,589,0

$ 

Contingency 21,525,000 $ 22,172,000 $ 14,981,000 $ 14,101,000 $ 72,779,0

$ 

AFUDC 10,947,000 $ 13,129,000 $ 8,698,000 $ 8,376,000 $ 41,150,0

$ 

Subtotal $ 57,367,000 53,016,000 $ 68,293,000 $ 36,536,000 $ 215,212,0

$ 

Total Capital Cost $ 147,926,000 141,834,000 $ 99,261,000 $ 94,390,000 $ 483,411,0

$ 

Levelized Capital Cost -- -- -- -- 42,305,0

$ 

Total Capital Cost (w/ fan sized for SCR only) -- -- -- 89,130,000 $ 478,151,0

$ 

Levelized Capital Cost (w/ fan sized for SCR only) -- -- -- -- 38,755,0

$ 

O&M Costs

Levelized Fixed O&M -- -- -- -- 1,466,0

$ 

Levelized Variable O&M -- -- -- -- 13,049,0

$ 

Levelized O&M Cost -- -- -- -- 14,515,0

$ 

Levelized Outage Cost -- -- -- -- 1,021,0

$ 

Total Levelized Capital, Outage and O&M Cost -- -- -- -- 54,291,0

$ 
Pro Forma FInancial Model NPPD Multi-Pollutant Removal StudyRevenue Requirement Determination

Analysis Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031Discount factor 0.9501 0.9027 0.8577 0.8149 0.7743 0.7356 0.6989 0.6641 0.6310 0.5995 0.5696 0.5412 0.5142 0.4885 0.4642 0.4410 0.4190 0.3981 0.3783 0.3594Capacity factor 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00%Energy production, GWh (with NPV) 56,866 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660Available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977SOX allowance surrender rate 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00Equivalent available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Equivalent SOX allowances used, tons (i.e., emissions) 00000000000000000000Equivalent SOX allowances sold(+)/bought(-) 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Tons SOX removed 00000000000000000000Available Hg allowances, oz. 2,984 2,984 2,984 3,047 3,047 3,047 3,047 3,047 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201Hg allowance surrender rate 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305Equivalent available Hg allowances, oz. 2,984 2,984 2,984 3,047 3,047 3,047 3,047 3,047 475 475 475 475 475 475 475 475 475 475 475 475Hg allowances used, oz. (i.e., emissions) 00000000000000000000Hg allowances sold(+)/bought(-) 5,969 5,969 5,969 6,095 6,095 6,095 6,095 6,095 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678Ounces Hg removed 00000000000000000000Tons NOX removed 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626 4,626Tons particulates removed 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800 109,800SOX allowance cost, $/ton (escalated values) $318 $337 $357 $265 $282 $299 $317 $333 $351 $368 $387 $407 $428 $450 $450 $450 $450 $450 $450 $450Hg allowance cost, $/oz.(escalated values) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Control system operating period masks

SOX 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Hg 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20NOX 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Particulates 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Fixed charge rates

SOX 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%

Hg 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%NOX 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%Particulates 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%

Total

Fixed charges on investment, $1000s NPV RR Levelized

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $233,400 $19,128 $23,923 $23,311 $22,698 $22,085 $21,473 $20,860 $20,247 $19,635 $19,022 $18,409 $17,797 $17,184 $16,571 $15,959 $15,346 $14,733 $14,121 $13,508 $12,895 $12,283

Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Total $233,400 $19,128 $23,923 $23,311 $22,698 $22,085 $21,473 $20,860 $20,247 $19,635 $19,022 $18,409 $17,797 $17,184 $16,571 $15,959 $15,346 $14,733 $14,121 $13,508 $12,895 $12,283

Extended outage purch power, $1000s

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $12,456 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021

Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Total $12,456 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021

Fixed O&M expense, $1000s

For SOX control:

Maintenance (labor + mat'l) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Operating labor $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For Hg control:

Maintenance (labor + mat'l) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Operating labor $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For NOX control:

Maintenance (labor + mat'l) $8,251 $676 $552 $566 $580 $594 $609 $624 $640 $656 $672 $689 $706 $724 $742 $761 $780 $799 $819 $840 $861 $882Operating labor $697 $57 $47 $48 $49 $50 $51 $53 $54 $55 $57 $58 $60 $61 $63 $64 $66 $68 $69 $71 $73 $75Total fixed O&M cost $8,947 $733 $599 $613 $629 $645 $661 $677 $694 $711 $729 $747 $766 $785 $805 $825 $846 $867 $888 $911 $933 $957

Variable O&M expense, $1000s

For SOX control:

Limestone $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Lime (90% available CaO) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Dibasic acid $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Water for SOX removal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0SO3 reduction agent (Na2CO3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Solid waste sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid waste landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For Hg control:

Powdered activated carbon $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Brominated activated carbon $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fuel additive $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For NOX control:

Urea $21,370 $1,751 $1,429 $1,465 $1,502 $1,539 $1,578 $1,617 $1,658 $1,699 $1,742 $1,785 $1,830 $1,876 $1,922 $1,971 $2,020 $2,070 $2,122 $2,175 $2,230 $2,285

Catalyst $28,415 $2,329 $1,901 $1,948 $1,997 $2,047 $2,098 $2,151 $2,204 $2,259 $2,316 $2,374 $2,433 $2,494 $2,556 $2,620 $2,686 $2,753 $2,822 $2,892 $2,965 $3,039Water for NOX removal $14 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $26,395 $2,163 $1,766 $1,810 $1,855 $1,901 $1,949 $1,998 $2,048 $2,099 $2,151 $2,205 $2,260 $2,317 $2,375 $2,434 $2,495 $2,557 $2,621 $2,687 $2,754 $2,823Aux. power, capacity charge $3,036 $249 $203 $208 $213 $219 $224 $230 $236 $241 $247 $254 $260 $266 $273 $280 $287 $294 $302 $309 $317 $325

For particulate control:

Bags $4,642 $380 $0 $0 $0 $0 $0 $0 $3,627 $0 $0 $0 $0 $0 $0 $4,312 $0 $0 $0 $0 $0 $0Cages $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash sales ($1,223) ($100) ($82) ($84) ($86) ($88) ($90) ($93) ($95) ($97) ($100) ($102) ($105) ($107) ($110) ($113) ($116) ($118) ($121) ($124) ($128) ($131)Flyash landfill cost $4,530 $371 $303 $311 $318 $326 $334 $343 $351 $360 $369 $378 $388 $398 $407 $418 $428 $439 $450 $461 $473 $484Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total variable O&M cost $87,179 $7,144 $5,521 $5,659 $5,801 $5,946 $6,094 $6,247 $10,030 $6,563 $6,727 $6,895 $7,067 $7,244 $7,425 $11,922 $7,801 $7,996 $8,196 $8,401 $8,611 $8,826

Fuel expense, $1000 $0 $0Total revenue requirement, $1000s $329,526 $27,005 $30,043 $29,583 $29,128 $28,676 $28,228 $27,784 $30,971 $26,909 $26,478 $26,052 $25,630 $25,213 $24,802 $28,706 $23,993 $23,596 $23,205 $22,820 $22,440 $22,066

Summary Revenue Requirements NPV RR LevelizedInvestment cost $233,400 $19,128 $23,923 $23,311 $22,698 $22,085 $21,473 $20,860 $20,247 $19,635 $19,022 $18,409 $17,797 $17,184 $16,571 $15,959 $15,346 $14,733 $14,121 $13,508 $12,895 $12,283Extended outage purchased power $12,456 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021 $1,021Fixed O&M $8,947 $733 $599 $613 $629 $645 $661 $677 $694 $711 $729 $747 $766 $785 $805 $825 $846 $867 $888 $911 $933 $957Variable O&M w/o allowances or aux. pwr. $57,747 $4,733 $3,552 $3,641 $3,732 $3,826 $3,921 $4,019 $7,747 $4,223 $4,328 $4,436 $4,547 $4,661 $4,778 $9,209 $5,019 $5,145 $5,274 $5,405 $5,540 $5,679Auxiliary power, energy charge $26,395 $2,163 $1,766 $1,810 $1,855 $1,901 $1,949 $1,998 $2,048 $2,099 $2,151 $2,205 $2,260 $2,317 $2,375 $2,434 $2,495 $2,557 $2,621 $2,687 $2,754 $2,823Auxiliary power, capacity charge $3,036 $249 $203 $208 $213 $219 $224 $230 $236 $241 $247 $254 $260 $266 $273 $280 $287 $294 $302 $309 $317 $325Allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $341,982 $28,026 $31,064 $30,604 $30,148 $29,696 $29,248 $28,805 $31,992 $27,930 $27,499 $27,073 $26,651 $26,234 $25,822 $29,727 $25,014 $24,617 $24,226 $23,841 $23,461 $23,087

Case 23: SCRUnit 1

Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProForma Page 1 of 1 
Pro Forma FInancial Model NPPD Multi-Pollutant Removal StudyRevenue Requirement Determination

Analysis Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031Discount factor 0.9501 0.9027 0.8577 0.8149 0.7743 0.7356 0.6989 0.6641 0.6310 0.5995 0.5696 0.5412 0.5142 0.4885 0.4642 0.4410 0.4190 0.3981 0.3783 0.3594Capacity factor 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00%Energy production, GWh (with NPV) 59,859 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906Available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977SOX allowance surrender rate 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00Equivalent available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Equivalent SOX allowances used, tons (i.e., emissions) 00000000000000000000Equivalent SOX allowances sold(+)/bought(-) 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Tons SOX removed 00000000000000000000Available Hg allowances, oz. 2,984 2,984 2,984 3,047 3,047 3,047 3,047 3,047 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201 1,201Hg allowance surrender rate 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305 2.5305Equivalent available Hg allowances, oz. 2,984 2,984 2,984 3,047 3,047 3,047 3,047 3,047 475 475 475 475 475 475 475 475 475 475 475 475Hg allowances used, oz. (i.e., emissions) 00000000000000000000Hg allowances sold(+)/bought(-) 5,969 5,969 5,969 6,095 6,095 6,095 6,095 6,095 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678 1,678Ounces Hg removed 00000000000000000000Tons NOX removed 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692 4,692Tons particulates removed 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365 111,365SOX allowance cost, $/ton (escalated values) $318 $337 $357 $265 $282 $299 $317 $333 $351 $368 $387 $407 $428 $450 $450 $450 $450 $450 $450 $450Hg allowance cost, $/oz.(escalated values) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Control system operating period masks

SOX 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Hg 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20NOX 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Particulates 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Fixed charge rates

SOX 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%

Hg 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%NOX 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%Particulates 10.25% 9.99% 9.73% 9.46% 9.20% 8.94% 8.68% 8.41% 8.15% 7.89% 7.63% 7.36% 7.10% 6.84% 6.58% 6.31% 6.05% 5.79% 5.53% 5.26%

Total

Fixed charges on investment, $1000s NPV RR Levelized

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $239,492 $19,627 $24,548 $23,919 $23,291 $22,662 $22,033 $21,405 $20,776 $20,147 $19,519 $18,890 $18,261 $17,633 $17,004 $16,375 $15,747 $15,118 $14,489 $13,861 $13,232 $12,603

Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Total $239,492 $19,627 $24,548 $23,919 $23,291 $22,662 $22,033 $21,405 $20,776 $20,147 $19,519 $18,890 $18,261 $17,633 $17,004 $16,375 $15,747 $15,118 $14,489 $13,861 $13,232 $12,603

Extended outage purch power, $1000s

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $13,112 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075

Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Total $13,112 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075

Fixed O&M expense, $1000s

For SOX control:

Maintenance (labor + mat'l) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Operating labor $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For Hg control:

Maintenance (labor + mat'l) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Operating labor $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For NOX control:

Maintenance (labor + mat'l) $8,251 $676 $552 $566 $580 $594 $609 $624 $640 $656 $672 $689 $706 $724 $742 $761 $780 $799 $819 $840 $861 $882Operating labor $697 $57 $47 $48 $49 $50 $51 $53 $54 $55 $57 $58 $60 $61 $63 $64 $66 $68 $69 $71 $73 $75Total fixed O&M cost $8,947 $733 $599 $613 $629 $645 $661 $677 $694 $711 $729 $747 $766 $785 $805 $825 $846 $867 $888 $911 $933 $957

Variable O&M expense, $1000s

For SOX control:

Limestone $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Lime (90% available CaO) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Dibasic acid $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Water for SOX removal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0SO3 reduction agent (Na2CO3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Solid waste sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid waste landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For Hg control:

Powdered activated carbon $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Brominated activated carbon $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fuel additive $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

For NOX control:

Urea $21,671 $1,776 $1,450 $1,486 $1,523 $1,561 $1,600 $1,640 $1,681 $1,723 $1,766 $1,810 $1,856 $1,902 $1,950 $1,998 $2,048 $2,099 $2,152 $2,206 $2,261 $2,317

Catalyst $28,877 $2,367 $1,932 $1,980 $2,029 $2,080 $2,132 $2,186 $2,240 $2,296 $2,354 $2,412 $2,473 $2,535 $2,598 $2,663 $2,729 $2,798 $2,868 $2,939 $3,013 $3,088Water for NOX removal $14 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1 $1Purchases (+) or sales (-) of allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, energy charge $26,395 $2,163 $1,766 $1,810 $1,855 $1,901 $1,949 $1,998 $2,048 $2,099 $2,151 $2,205 $2,260 $2,317 $2,375 $2,434 $2,495 $2,557 $2,621 $2,687 $2,754 $2,823Aux. power, capacity charge $3,036 $249 $203 $208 $213 $219 $224 $230 $236 $241 $247 $254 $260 $266 $273 $280 $287 $294 $302 $309 $317 $325

For particulate control:

Bags $4,642 $380 $0 $0 $0 $0 $0 $0 $3,627 $0 $0 $0 $0 $0 $0 $4,312 $0 $0 $0 $0 $0 $0Cages $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash sales ($1,240) ($102) ($83) ($85) ($87) ($89) ($92) ($94) ($96) ($99) ($101) ($104) ($106) ($109) ($112) ($114) ($117) ($120) ($123) ($126) ($129) ($133)Flyash landfill cost $4,594 $377 $307 $315 $323 $331 $339 $348 $356 $365 $374 $384 $393 $403 $413 $424 $434 $445 $456 $468 $479 $491Aux. power, energy charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Aux. power, capacity charge $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total variable O&M cost $87,989 $7,211 $5,575 $5,715 $5,858 $6,004 $6,154 $6,308 $10,093 $6,627 $6,793 $6,963 $7,137 $7,315 $7,498 $11,997 $7,878 $8,075 $8,277 $8,483 $8,696 $8,913

Fuel expense, $1000 $0 $0Total revenue requirement, $1000s $336,428 $27,571 $30,722 $30,247 $29,777 $29,310 $28,848 $28,390 $31,563 $27,486 $27,041 $26,600 $26,164 $25,733 $25,307 $29,197 $24,470 $24,059 $23,654 $23,255 $22,861 $22,473

Summary Revenue Requirements NPV RR LevelizedInvestment cost $239,492 $19,627 $24,548 $23,919 $23,291 $22,662 $22,033 $21,405 $20,776 $20,147 $19,519 $18,890 $18,261 $17,633 $17,004 $16,375 $15,747 $15,118 $14,489 $13,861 $13,232 $12,603Extended outage purchased power $13,112 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075 $1,075Fixed O&M $8,947 $733 $599 $613 $629 $645 $661 $677 $694 $711 $729 $747 $766 $785 $805 $825 $846 $867 $888 $911 $933 $957Variable O&M w/o allowances or aux. pwr. $58,557 $4,799 $3,607 $3,697 $3,789 $3,884 $3,981 $4,080 $7,810 $4,287 $4,394 $4,504 $4,617 $4,732 $4,850 $9,283 $5,096 $5,223 $5,354 $5,488 $5,625 $5,766Auxiliary power, energy charge $26,395 $2,163 $1,766 $1,810 $1,855 $1,901 $1,949 $1,998 $2,048 $2,099 $2,151 $2,205 $2,260 $2,317 $2,375 $2,434 $2,495 $2,557 $2,621 $2,687 $2,754 $2,823Auxiliary power, capacity charge $3,036 $249 $203 $208 $213 $219 $224 $230 $236 $241 $247 $254 $260 $266 $273 $280 $287 $294 $302 $309 $317 $325Allowances $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $349,540 $28,646 $31,796 $31,322 $30,851 $30,385 $29,923 $29,464 $32,637 $28,560 $28,115 $27,675 $27,239 $26,808 $26,382 $30,272 $25,545 $25,134 $24,729 $24,329 $23,935 $23,548

Case 24: SCRUnit 2

Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProForma Page 1 of 1 
Nebraska Public Power District 

General Gentleman Station, Units 1&2 

 Project No. 12194-001 

2/7/2008 

Page 1 of 2 

Basis of Estimate

Scope

This cost is based on installing a selective catalytic reduction (SCR) system on Gerald Gentleman Station, Units 1 & 

2. 

Scope includes: 

• Unit 1 SCR Area 

• Unit 2 SCR Area 

• Units 1&2 Common Areas (Urea to Ammonia System, Relocation) 

• Auxiliary Power System 

• Booster ID Fans 

Assumptions

1. All work is performed on a 5-day 10-hour workweek. 

2. $10/hour included for per diem. 

3. The following conditions apply: 

• Major design parameters established 

• Major equipment identified 

• Conceptual general arrangement drawings 

• EPC contracting approach for estimate basis 

Commercial Basis

1. Equipment/Material Cost

Based on vendor budgetary quotes, estimated quantities and S&L in-house data base. 

2. Labor Wage Rates

Crew Labor Rates have been developed using the Union Craft rates and fringe benefits from the 

Omaha, Nebraska area. Costs have been added to cover F.I.C.A., workers compensation, all applicable 

taxes, small tools, incidentals, construction equipment and contractor’s overhead. 

3. Labor Crews

The construction/erection labor cost is based on the use of applicable construction crews typically 

required for projects of this type. 

4. Productivity

No allowances have been made to cover items such as the loss in productivity because of inability to 

attract labor, weather conditions, etc. 

5. Quantity Sources

All quantity data was developed internally by S&L Lead Engineers. 

6. Project Schedule

To be determined. 

7. Indirect Expenses

The engineering costs included herein are estimated and are not to be interpreted as a proposal by S&L 

to perform engineering services. 
Nebraska Public Power District 

General Gentleman Station, Units 1&2 

 Project No. 12194-001 

2/7/2008 

Page 2 of 2 

BOP engineering is included and would be part of the EPC price. Also included, Owner’s A-E 

Engineering, Owner’s Construction Management, General Owner’s Costs and Owner’s Bond Fees. 

8. Escalation Rates (See Cost Summary for rates)

Estimated at 5.0% for Equipment, 7.0% for Material, 4.0% for Labor and 6.0% for Indirects. 

9. Sales/Use Taxes (See Cost Summary for rates)

Estimated at 5.50% of Equipment and Material. 

10. Contingency (See Cost Summary for rates)

Estimated at 20% for Equipment, Material, Labor and Indirects. 

11. AFUDC Rate (See Cost Summary for rates)

Estimated at 5.0% from 2009. 

12. Bond Fees (See Cost Summary for rates)

Estimated at 2.5% of $200,000,000. 

13. General Owner’s Cost (See Cost Summary for rates)

Estimated at 2.0% of Total Construction Cost. 
Nebraska Public Power District Project No, 12194-001 

Gerald Gentleman Station Unit 1&2 2/7/2008 

Basis of SCR Costs 

 

Technical Basis

The following is a summary of the technical basis of the Phase 1 selective catalytic 

reduction (SCR) system capital cost estimate and the Unit 1 and 2 ID Fan and Aux Power 

system capital cost estimate. 

1. Urea to Ammonia System common to both Units 

a. Three dry Urea day bins, one per unit and one common spare 

b. Three urea solution storage tank, approx. 14 days, one per unit and one 

common spare 

c. Three hydrolyzers one per Unit with one common spare 

d. Ammonia injection lances/injectors with static mixers 

e. Vendor quote from Fuel Tech 

2. Reactor per Unit 

a. 2 reactors per unit, approx. 48’W x 52’ L x 49’ H each. 

b. 3 layers of catalyst per reactor, approx. 1,300 m3, and one unfilled spare layer 

c. Constructed of carbon steel 

d. Structural steel for support 

e. Stairs and access platforms 

f. Sonic horns and sootblowers 

g. Flow model study 

h. Reactor bypass dampers 

i. 6” insulation and lagging 

j. Hoists 

k. Rainhood 

3. Flues Including Support Steel per Unit

a. Economizer outlet to SCR inlet 

i. Carbon steel. 

ii. Velocity = 4000 to 4500 fpm. 

iii. 6” insulation with lagging. 

b. SCR reactor riser ductwork 

i. Carbon steel 

ii. Velocity 4000 fpm. 

iii. 6” insulation with lagging. 

c. SCR outlet 

iv. Carbon steel. 

v. Velocity = 4000 to 4500 fpm. 

vi. 6” insulation with lagging. 

d. Includes stairways and access platforms to the catalyst layers 

4. Control System Modifications common to both Units

a. Based on number of I/O points, approx. 472 per Unit 
Nebraska Public Power District Project No, 12194-001 

Gerald Gentleman Station Unit 1&2 2/7/2008 

Basis of SCR Costs 

 

b. NOx analyzers, inlet of SCR 

c. Ammonia slip analyzers, inlet and outlet of SCR. 

5. Subsurface and Foundation Work-All

a. Foundation system consists of drilled caissons. 

b. The ESP mat might be re-used. This will be evaluated in detail engineering. 

6. Civil Work-All

a. Roads around SCR reactor boxes. 

b. White Rock surfacing. 

12. Demolition, Modification and Reinforcement

a. Demolition of existing ESP casings and support steel to the ground level. 

b. Reinforcement of some existing ESP support steel on Unit 1. 

c. Economizer modifications (added surface area) to reduce temperature to 

avoid sintering the catalyst. GGS boilers operate at temperatures above 

800degF. Design basis for the SCR is 780 degF. 

d. Air heater inlet duct reinforcement due to increased pressure drop from the 

SCR. 

e. Unit 2 ESP hot duct bypass completion including insulation and lagging 

f. No credit has been given to reusing equipment, foundations, expansion joints 

or steel in the SCR estimate. 

g. Sturdier J-Hooks will need to be purchased during bag change out prior to 

installation of an SCR. Increased SO3 concentration in the flue gas associated 

with the catalyst can lead to SO3 condensation from the flue gas reacting with 

Iron Oxide in the ash. The resulting Iron Sulfate can cement the fly ash to the bag 

leading to higher bag weights. This was not included in the cost estimate. 

13. Pipe Racks common to both Units

 a. From U2A system to each reactor on each Unit. 

b. Credit was not taken for reusing existing pipe racks since S&L did not walk 

this down. This will be looked at in detail engineering. 

14. CEMS per Unit

 a. Re-use existing CEMS. 

15. Instrument Air common to both Units 

a. One air receiver, 1000 gallon used to provide local instrument air storage 

capacity. 

 b. No compressors included. 

16. Field Painting-All

a. Multiple coat system used for exposed ductwork only. 

 b. Inorganic zinc primer and polyurethane system used for steel. 
Nebraska Public Power District Project No, 12194-001 

Gerald Gentleman Station Unit 1&2 2/7/2008 

Basis of SCR Costs 

 

17. Performance Testing- All

 a. Not included. Part of Owner’s costs. 

18. Piping common to both Units

a. Demineralized water supply to U2A system 

b. Instrument air piping to U2A system and sonic horns 

c. Steam piping to hydrolyzer skids 

c. Heat traced piping for ammonia delivery lines. 

d. Sootblowing pipe to top of catalyst 

e. Vacuum piping from ground to catalyst levels 

19. Miscellaneous Mechanical common to both Units

a. Reverse osmosis tank, 500,000 gallons. 

b. Urea to ammonia area sump for any washdown or drain water and 

condensate generated from the hydrolyzers in the urea to ammonia system. 

20. Installation- All

21. New booster ID fans-All

a. Two 10,000 hp axial ID fans per Unit. Duplicate of the existing ID fans 

capable of providing enough static head for an FGD retrofit. These fans are sized 

to overcome pressure drop associated with both an SCR and FGD. If only one 

system is installed, the hp and price can be reduced. 

b. Vendor quote from TLT Babcock. 

c. Includes foundations and motors. 

22. Electrical-All

 a. One start up transformer. 

 b. Two unit auxiliary transformer. 

 c. Medium voltage switch-gear. 

 d. 480 V switch-gear for reagent prep, dewatering, absorber and SCR. 

e. Two transformer electrical equipment buildings. Includes a single circuit 

breaker for unit aux transformer located on the turbine floor. 

f. Two main electrical equipment buildings. 

g. General area lighting. 

23. Test Port-All

a. Included in the ductwork costs. 

24. Safety-All

a. Sensors in the urea to ammonia system area and injection grid to sense 

ammonia 

b. Eye wash stations and showers 
Nebraska Public Power District

Gerald Gentleman Station Unit 1 & 2 Estimate Summary for SCR 

Equipment 

Cost 

($ Millions)

Material Cost 

($ Millions)

Labor Cost 

($ Millions)

Erection Labor 

Man-Hours

Total Cost 

($ Millions)

Normalized Cost 

($/kW)

Unit 1 SCR Area (Estimate No. 23288B)

Direct 9.906 21.702 42.407 340,655 74.015EPC portion 0.000 0.000 14.803 0 14.803Indirect 0.000 0.000 0.000 0 1.776Escalation 0.000 0.000 0.000 0 17.030Sales/Use Tax 0.000 0.000 0.000 0 1.738AFUDC 0.000 0.000 0.000 0 10.947Contingency @ 20% 0.000 0.000 0.000 0 21.525

Unit 2 SCR Area (Estimate No. 23296B)

Direct 9.905 22.142 43.419 357,986 75.466EPC portion 0.000 0.000 15.093 0 15.093Indirect 0.000 0.000 0.000 0 1.811Escalation 0.000 0.000 0.000 0 18.492Sales/Use Tax 0.000 0.000 0.000 0 1.763AFUDC 0.000 0.000 0.000 0 13.129Contingency @ 20% 0.000 0.000 0.000 0 22.172

Unit 1 & 2 Common Area (Estimate No. 23297B)

Direct 8.852 3.494 9.318 68,528 21.664EPC portion 0.000 0.000 9.304 0 9.304Indirect 0.000 0.000 0.000 0 30.468Escalation 0.000 0.000 0.000 0 13.467Sales/Use Tax 0.000 0.000 0.000 0 0.679AFUDC 0.000 0.000 0.000 0 8.698Contingency @ 20% 0.000 0.000 0.000 0 14.981

Unit 1 & 2 Auxil. Power & ID Fans (Estimate No. 23298B)

Direct 19.294 6.332 22.586 260,997 48.212EPC portion 0.000 0.000 9.642 0 9.642Indirect 0.000 0.000 0.000 0 1.157Escalation 0.000 0.000 0.000 0 11.493Sales/Use Tax 0.000 0.000 0.000 0 1.409AFUDC 0.000 0.000 0.000 0 8.376Contingency @ 20% 0.000 0.000 0.000 0 14.101

Project Totals

Direct 47.957 53.670 117.730 1,028,166 219.357EPC portion 0.000 0.000 48.842 0 48.842Indirect 0.000 0.000 0.000 0 35.212Escalation 0.000 0.000 0.000 0 60.482Sales/Use Tax 0.000 0.000 0.000 0 5.589AFUDC 0.000 0.000 0.000 0 41.150Contingency @ 20% 0.000 0.000 0.000 0 72.779

"All In" Grand Total with EPC Fee = 483.411 322

Grand Total without EPC Fee = 434.569 290

Price Level = Q4, 2007

Page 1 of 1


















A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 1 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-1SCR01 

B 

 1 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS1SCR0101.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

NORTH

> PRIMARY AIR FANS

ELECTRICAL

EQUIPMENT

BUILDING

MECHANICAL

CONTROL

BUILDING

> FORCED DRAFT FAN

 (TYP.)

> CHIMNEY

PLAN PLAN @ GRADE

SCR

BYPASS

MODE

SOOT BLOWERS

FIRST CATALYST

LAYER ONLY)

SONIC HORN

(TYP.)

OUTLINE OF EXISTING

PRECIPITATOR FOUNDATION

(T/CONC. EL. 3112’-0" 

9’ THICK SLAB)

CATALYST

HOIST AREA FLAP DAMPER

CATALYST LOADING DOORS

(TYP.)

ELECTRICAL

BUILDING

(15’ X 60’)

CATALYST

HOIST AREA

NEW

WAREHOUSE,

MACHINE SHOP

& SERVICE BUILDING

ACCESS

AISLE

GAS DUCT

33’-0"

X

34’-0"

ECONOMIZER OUTLETS

33’-1 13/16 " X 17’-6"

BOILER

BUILDING

PRECIPITATOR

(ABANDONED)

OUTLINE OF

SCR ABOVE

B

SHT 3

B

NOTES:

1. UREA TRUCK UNLOADING, SOLUTION 

PREPARATION AREA AND HYDROLYZER SKIDS ARE 

WITHIN UNIT 2 (SEE MS-1SCR01 SHEET 1). AN 

EMERGENCY BACKUP HYDROLYZER SKID IS ALSO 

WITHIN THIS AREA WITH A BACKUP CROSS-TIE PIPE 

CONNECTED TO BOTH UNIT’S SCR AMMONIA 

INJECTION GRIDS.

2. THE REMAINING PORTIONS OF THE ABANDONED 

PRECIPITATORS AND FOUNDATION PEDESTALS TO BE 

REMOVED AS REQUIRED.
A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 1 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-1SCR01 

B 

 3 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS1SCR0101.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

B/GAS DUCT

EL. 3235’-6"

EL. 3118

GRADE

> TEMPERATING AIR DUCT

EL. 3191’-7"

> PRIMARY AIR DUCT

EL. 3173’-6"

> SECONDARY AIR DUCT

EL. 3156’-6"

T/DUCT

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

SCR

52’-1 1/4 " 

X

47’-2 1/2 "

X

49’-0" HIGH

(LOOKING EAST)

SECTION B-B

CATALYST HOIST AREA

> FORCED DRAFT FAN

EL. 3137’-0"

AIG

PLANT COAL CONVEYOR

ELECTRICAL EQUIPMENT BUILDING

(EXISTING)

ELECTRICAL

EQUIPMENT

BUILDING

EL. 3356’-6"

EL. 3320’-0"

EL. 3308’-0"

EL. 3296’-0"

EL. 3284’-0"

EL. 3273’-6"

AMMONIA GAS SUPPLY PIPE
A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 1 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-1SCR01 

B 

 2 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS1SCR0102.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

ELECTRICAL BUILDING

CATALYST HOIST AREA

B/GAS DUCT

B/ECONOMIZER OUTLET

T/BOILER BUILDING

T/DUCT

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

EL. 3382’-0"

EL. 3235’-6"

EL. 3225’-3"

EL. 3118

GRADE

2 OUTLETS @

17’-6"

X

33’-1 13/16 "

SOOT BLOWERS

SONIC HORNS (TYP.)

CATALYST LOADING DOORS (TYP.)

NOX TUNING GRID

NEW

> TEMPERATING AIR DUCT

EL. 3191’-7"

> PRIMARY AIR DUCT

EL. 3173’-6"

> SECONDARY AIR DUCT

EL. 3156’-6"

MECHANICAL

CONTROL

BUILDING

> PRIMARY AIR FANS

> FORCED DRAFT FANS

EL. 3137’-0"

EL. 3129’-6"

SCR

17’-6 "

X

52’-1 1/4 "

AIG

FLOW STRAIGHTENERS

47’-2 1/2 "

X

52’-1 1/4 "

X

49’-0" HIGH

34’-0"

X

33’-0"

PRIMARY AIR

AIR PREHEATER

SECONDARY AIR

AIR PREHEATER

SECTION A-A

(LOOKING NORTH)

EL. 3356’-6"

EL. 3320’-0"

EL. 3308’-0"

EL. 3296’-0"

EL. 3284’-0"

EL. 3273’-6"
A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 2 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-2SCR01 

B 

 1 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS2SCR0101.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

NORTH

UREA

SOLUTION

TANK

CATALYST

HOIST AREA

FLAP DAMPER CATALYST

HOIST AREA

ELECTRICAL

BUILDING

(15’ X 60’)

MECHANICAL

BUILDING

> PRIMARY AIR FAN

> FORCED DRAFT FAN

(TYP.)

PRECIPITATOR

ELECTRICAL

EQUIPMENT

BUILDING

BYPASS

MODE

SCR

OUTLINE OF

SCR ABOVE

PRECIPITATOR

(ABANDONED)

BOILER

BUILDING

SOOT BLOWERS

FIRST CATALYST

LAYER ONLY)

SONIC HORN

(TYP.)

OUTLINE OF EXISTING

PRECIPITATOR FOUNDATION

(T/CONC. EL. 3112’-0" 

6’ THICK SLAB)

CATALYST LOADING DOORS

(TYP.)

ACCESS

AISLE

ECONOMIZER OUTLETS

34’-6" X 19’-0"

NEW

PLAN @ GRADE PLAN

B

B

SHT 3

GAS DUCT

41’-0"

X

28’-6"

NOTES:

1. UREA TRUCK UNLOADING, SOLUTION PREPARATION 

AREA AND HYDROLYZER SKIDS SERVICE UNIT 1 

ALSO.

2. THE REMAINING PORTIONS OF THE ABANDONED 

PRECIPITATORS AND FOUNDATION PEDESTALS TO BE 

REMOVED AS REQUIRED.

3. THE BAGHOUSE DUCT TIE-IN MUST PERFORMED 

BEFORE ANY PRECIPITATOR DEMOLITION/SCR 

CONSTUCTION MAY BEGIN.
A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 2 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-2SCR01 

B 

 3 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS12SCR0103.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

B/GAS DUCT

EL. 3235’-6"

EL. 3118

GRADE

SCR

(LOOKING EAST)

SECTION B-B

CATALYST HOIST AREA

AIG

ELECTRICAL

EQUIPMENT

BUILDING

T/DUCT

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

55’-2 1/2 " 

X

47’-2 1/2 "

X

49’-0" HIGH

HYROLYZER

SKIDS

EL. 3350-6"

EL. 3312’-6"

EL. 3300’-6"

EL. 3288’-6"

EL. 3276’-6"

EL. 3266’-0"
A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 UNIT 2 SCR- OPTION 1 

 GENERAL ARRANGEMENT 

 MS-2SCR01 

B 

 2 

12194-001

 

 

 

 

 

CONTRACTOR/INSTALLER SHALL TAKE ALL APPROPRIATE

PRECAUTIONS TO ENSURE THE SAFETY OF ALL PEOPLE

LOCATED ON THE WORK SITE, INCLUDING 

CONTRACTOR’S/INSTALLER’S PERSONNEL 

(OR THAT OF ITS SUBCONTRACTOR(S)) PERFORMING 

THE WORK.

 A 10-31-2007 D.SKOIRCHET D.G.SLOAT -------- 

 B 11-27-2007 D.SKOIRCHET D.G.SLOAT -------- 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MS2SCR0102.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

 1/16 "=1’-0"

16’ 0’ 16’ 32’ 48’ 64’

CATALYST HOIST AREA

B/GAS DUCT

B/ECONOMIZER OUTLET

T/BOILER BUILDING

T/DUCT

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

T/PLATFORM

EL. 3382’-0"

EL. 3118

GRADE

SOOT BLOWERS

SONIC HORNS (TYP.)

CATALYST LOADING DOORS (TYP.)

NOX TUNING GRID

SCR

AIG

FLOW STRAIGHTENERS

SECTION A-A

(LOOKING NORTH)

28’-6"

X

41’-0"

SECONDARY AIR DUCT

PRIMARY AIR DUCT

TEMPERATING AIR DUCT

EL. 3203’-8"

EL. 3136’-6"

EL. 3151’-7"

EL. 3253’-9"

EL. 3233’-6 5/16 "

2 OUTLETS @

19’-0"

X

34’-6 "

19’-0"

X

55’-2 1/2 "

47’-2 1/2 "

X

55’-1 1/2 "

X

49’-0" HIGH

MECHANICAL

BUILDING

AIR PREHEATERS

EL. 3128’-0"

> FORCED DRAFT & PRIMARY AIR FANS

> PRIMARY AIR FANS

> FORCED DRAFT FANS

EL. 3350-6"

EL. 3312’-6"

EL. 3300’-6"

EL. 3288’-6"

EL. 3276’-6"

EL. 3266’-0"