# 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 ReductionCapital and O&M CostsGGS Unit 1 GGS Unit 2 Common Facilities Auxiliary Power/ID Fans TOTAL STATIONCapital CostsSCR Area 2,316,000$ 2,316,000$ -$ -$ 4,632,000$Civil/SiteWork 710,000$ 710,000$ -$ -$ 1,420,000$Flue Gas System/Ductwork 37,022,000$ 38,442,000$ -$ -$ 75,464,000$Modifications 6,038,000$ 6,038,000$ -$ -$ 12,076,000$Catalyst 9,216,000$ 9,216,000$ -$ -$ 18,432,000$Common Structures/Buildings -$ -$ 1,185,000$ -$ 1,185,000$Urea to AmmoniaSystem -$ -$ 11,232,000$ -$ 11,232,000$Miscellaneous Mechanical Items 513,000$ 678,000$ 1,495,000$ -$ 2,686,000$Pipe Rack 876,000$ 876,000$ -$ -$ 1,752,000$Booster Fans -$ -$ -$ 12,205,000$ 12,205,000$Instrumentation and Controls -$ -$ 2,040,000$ -$ 2,040,000$Allowance for Additonal Cranes -$ -$ 2,000,000$ -$ 2,000,000$Electrical Modifications -$ -$ -$ 25,962,000$ 25,962,000$Mobilization/Demobilization - 1% of Labor 294,000$ 307,000$ 65,000$ 150,000$ 816,000$Cost Due to Overtime - 5-10's 4,249,000$ 4,365,000$ 935,000$ 2,244,000$ 11,793,000$Per Diem 3,407,000$ 2,864,000$ 685,000$ 2,610,000$ 9,566,000$Spare Parts - 3% of Equipment 275,000$ 275,000$ 246,000$ 536,000$ 1,332,000$Freight 1,376,000$ 1,394,000$ 484,000$ 1,157,000$ 4,411,000$General & Administration - 5% of Material and Labor 2,574,000$ 2,662,000$ 432,000$ 1,116,000$ 6,784,000$Profit - 10% of Material and Labor 5,149,000$ 5,323,000$ 865,000$ 2,232,000$ 13,569,000$EPC Fee - 20% of Total Cost 14,803,000$ 15,093,000$ 9,304,000$ 9,642,000$ 48,842,000$Subtotal88,818,000$ 90,559,000$ 30,968,000$ 57,854,000$ 268,199,000$Other CostsIndirect 1,776,000$ 1,811,000$ 30,468,000$ 1,157,000$ 35,212,000$Escalation 17,030,000$ 18,492,000$ 13,467,000$ 11,493,000$ 60,482,000$Sales/Use Tax 1,738,000$ 1,763,000$ 679,000$ 1,409,000$ 5,589,000$Contingency 21,525,000$ 22,172,000$ 14,981,000$ 14,101,000$ 72,779,000$AFUDC 10,947,000$ 13,129,000$ 8,698,000$ 8,376,000$ 41,150,000$Subtotal53,016,000$ 57,367,000$ 68,293,000$ 36,536,000$ 215,212,000$Total Capital Cost141,834,000$ 147,926,000$ 99,261,000$ 94,390,000$ 483,411,000$Levelized Capital Cost-- -- -- -- 42,305,000$Total Capital Cost (w/ fan sized for SCR only)-- -- -- 89,130,000$ 478,151,000$Levelized Capital Cost (w/ fan sized for SCR only)-- -- -- -- 38,755,000$O&M CostsLevelized Fixed O&M -- -- -- -- 1,466,000$Levelized Variable O&M -- -- -- -- 13,049,000$Levelized O&M Cost-- -- -- -- 14,515,000$Levelized Outage Cost-- -- -- -- 1,021,000$Total Levelized Capital, Outage and O&M Cost-- -- -- -- 54,291,000$Sargent & Lundy LLCPro Forma FInancial ModelNPPD Multi-Pollutant Removal StudyRevenue Requirement DeterminationAnalysis Year1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031Discount factor0.9501 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 factor80.00% 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 14,97714,977 14,977 14,977 14,977 14,977 14,977Tons SOX removed00000000000000000000Available 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 removed00000000000000000000Tons NOX removed4,626 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 masksSOX1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Hg1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20NOX1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Particulates1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Fixed charge ratesSOX10.25% 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%Hg10.25% 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%NOX10.25% 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%Particulates10.25% 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%TotalFixed charges on investment, $1000s NPV RR LevelizedSOX $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 $12,283Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $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 purch power, $1000sSOX $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 $1,021Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total$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 expense, $1000sFor 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 $0For 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 $0For 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 $957Variable O&M expense, $1000sFor 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 $0SO3reduction agent (Na2CO3)$0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid 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 $0For 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 $0For 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 $2,285Catalyst $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 $325For 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 $8,826Fuel 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 $22,066Summary Revenue RequirementsNPV 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 $23,087Case 23: SCRUnit 1Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/12/2008, 4:35 PMSargent & Lundy LLCPro Forma FInancial ModelNPPD Multi-Pollutant Removal StudyRevenue Requirement DeterminationAnalysis Year1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031Discount factor0.9501 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 factor80.00% 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 14,97714,977 14,977 14,977 14,977 14,977 14,977Tons SOX removed00000000000000000000Available 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 removed00000000000000000000Tons NOX removed4,692 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 masksSOX1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Hg1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20NOX1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Particulates1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Fixed charge ratesSOX10.25% 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%Hg10.25% 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%NOX10.25% 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%Particulates10.25% 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%TotalFixed charges on investment, $1000s NPV RR LevelizedSOX $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 $12,603Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $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 purch power, $1000sSOX $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 $1,075Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total$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 expense, $1000sFor 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 $0For 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 $0For 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 $957Variable O&M expense, $1000sFor 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 $0SO3reduction agent (Na2CO3)$0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid 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 $0For 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 $0For 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 $2,317Catalyst $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 $325For 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 $8,913Fuel 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 $22,473Summary Revenue RequirementsNPV 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 $23,548Case 24: SCRUnit 2Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/12/2008, 4:35 PM

### 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 redu ction (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 th e 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 pr oductivity 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 Dist rict 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 Un it 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, a pprox. 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 Dist rict 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 bo ilers 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 reus ing 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 c oncentration in the flue gas associated with the catalyst can lead to SO3 conde nsation from the flue gas reacting with Iron Oxide in the ash. The resulting Iron Su lfate 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 ex isting pipe racks since S&L did not walk

this down. This will be looke d 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 a nd polyurethane system used for steel.

## Nebraska Public Power Dist rict 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 hydrolyzer s 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 w ith 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 pr ep, dewatering, absorber and SCR. e. Two transformer electrical equipm ent buildings. Includes a single circuit

breaker for unit aux transforme r 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 showersNebraska Public Power DistrictGerald Gentleman Station Unit 1 & 2Estimate Summaryfor SCR12194-0012/7/2008EquipmentCost($ Millions)Material Cost($ Millions)Labor Cost($ Millions)Erection LaborMan-HoursTotal 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 21.525Unit 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 22.172Unit 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 14.981Unit 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 14.101Project TotalsDirect 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 322Grand Total without EPC Fee = 434.569 290Price Level = Q4, 2007Page 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.

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

-------- A

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

-------- FILENAME:MS1SCR0101.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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.

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

-------- A

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

-------- FILENAME:MS1SCR0101.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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.

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

-------- A

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

-------- FILENAME:MS1SCR0102.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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.

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

-------- A

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

-------- FILENAME:MS2SCR0101.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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 PLAN @ GRADE 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.

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

-------- A

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

-------- FILENAME:MS12SCR0103.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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.

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

-------- A

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

-------- FILENAME:MS2SCR0102.DGN

DESIGN FREEZE FOR COMMENTS 

### 1/16 "=1’-0" 0’ 16’ 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"