# DRY FGD 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 Spray Dryer Absorber Area (Estimate No. 22993B)

- Unit 2 Spray Dryer Absorber Area (Estimate No. 22999B)

- Units 1&2 Common (Estimate No. 22994B)

- Auxiliary Power and Booster ID Fans (Estimate No. 22998B)

General Arrangement of Dry FGD

Color 3-D General Arrangement of Dry FGD (New Equipment in Teal)Spray Dryer AbsorberCapital and O&M CostsGGS Unit 1 GGS Unit 2 Common Facilities Auxiliary Power/ID Fans TOTAL STATIONCapital CostsSpray Dryer Absorber Area 48,377,000$ 48,377,000$ -$ -$ 96,754,000$Civil/SiteWork 2,457,000$ 2,530,000$ -$ -$ 4,987,000$Flue Gas System/Ductwork 48,404,000$ 49,824,000$ -$ -$ 98,228,000$Baghouse Modifications 13,284,000$ 13,284,000$ -$ -$ 26,568,000$Reagent Preparation System -$ -$ 19,671,000$ -$ 19,671,000$Waste Recycle System -$ -$ 12,518,000$ -$ 12,518,000$Common Structures/Buildings -$ -$ 14,616,000$ -$ 14,616,000$Reagent Handling System -$ -$ 16,284,000$ -$ 16,284,000$Fly Ash Handling Modifications -$ -$ 21,529,000$ -$ 21,529,000$Track Ladders and Switches -$ -$ 2,604,000$ -$ 2,604,000$Miscellaneous Mechanical Items 2,764,000$ 2,391,000$ 3,557,000$ -$ 8,712,000$Pipe Rack -$ -$ 6,570,000$ -$ 6,570,000$Booster Fans -$ -$ -$ 13,006,000$ 13,006,000$Instrumentation and Controls -$ -$ 3,513,000$ -$ 3,513,000$Electrical Modifications -$ -$ -$ 25,816,000$ 25,816,000$Mobilization/Demobilization - 1% of Labor 636,000$ 646,000$ 462,000$ 146,000$ 1,890,000$Cost Due to Overtime - 5-10's 8,540,000$ 8,673,000$ 6,196,000$ 1,959,000$ 25,368,000$Per Diem 7,921,000$ 7,880,000$ 7,109,000$ 2,746,000$ 25,656,000$Spare Parts - 3% of Equipment 801,000$ 801,000$ 1,064,000$ 596,000$ 3,262,000$Freight 1,248,000$ 1,255,000$ 961,000$ 1,242,000$ 4,706,000$General & Administration - 5% of Material and Labor 4,857,000$ 4,919,000$ 3,579,000$ 1,046,000$ 14,401,000$Profit - 10% of Material and Labor 9,713,000$ 9,838,000$ 7,159,000$ 2,091,000$ 28,801,000$EPC Fee - 20% of Total Cost 29,800,000$ 30,084,000$ 30,754,000$ 9,729,000$ 100,367,000$Subtotal178,802,000$ 180,502,000$ 158,146,000$ 58,377,000$ 575,827,000$Other CostsIndirect 3,573,000$ 3,610,000$ 39,101,000$ 1,168,000$ 47,452,000$Escalation 33,071,000$ 35,590,000$ 40,232,000$ 11,556,000$ 120,449,000$Sales/Use Tax 3,160,000$ 3,169,000$ 3,278,000$ 1,470,000$ 11,077,000$Contingency 43,089,000$ 43,940,000$ 47,496,000$ 14,220,000$ 148,745,000$AFUDC 21,889,000$ 25,989,000$ 26,973,000$ 8,451,000$ 83,302,000$Subtotal104,782,000$ 112,298,000$ 157,080,000$ 36,865,000$ 411,025,000$Total Capital Cost283,584,000$ 292,800,000$ 315,226,000$ 95,242,000$ 986,852,000$Levelized Capital Cost-- -- -- -- 80,875,000$Total Capital Cost (w/ fan sized for FGD only)-- -- -- 89,982,000$ 981,592,000$Levelized Capital Cost (w/ fan sized for FGD only)-- -- -- -- 80,013,000$O&M CostsLevelized Fixed O&M -- -- -- -- 7,812,000$Levelized Variable O&M -- -- -- -- 19,994,000$Levelized O&M Cost-- -- -- -- 27,806,000$Levelized Outage Cost-- -- -- -- 698,000$Total Levelized Capital, Outage and O&M Cost-- -- -- -- 108,517,000$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 Year2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032Discount 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) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128) (2,128)Equivalent SOX allowances sold(+)/bought(-) 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,849 12,84912,849 12,849 12,849 12,849 12,849 12,849Tons SOX removed40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426 40,426Available Hg allowances, oz. 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 1,201 1,201Hg allowance surrender rate 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 2.5305 2.5305Equivalent available Hg allowances, oz. 2,984 2,984 3,047 3,047 3,047 3,047 3,047 475 475 475 475 475 475 475 475 475 475 475 475 475Hg allowances used, oz. (i.e., emissions) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549) (10,549)Hg allowances sold(+)/bought(-) (4,580) (4,580) (4,454) (4,454) (4,454) (4,454) (4,454) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871) (8,871)Ounces Hg removed00000000000000000000Tons NOX removed00000000000000000000Tons particulates removed00000000000000000000SOX allowance cost, $/ton (escalated values) $337 $357 $265 $282 $299 $317 $333 $351 $368 $387 $407 $428 $450 $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 $483,558 $39,629 $49,565 $48,295 $47,026 $45,757 $44,487 $43,218 $41,949 $40,679 $39,410 $38,141 $36,871 $35,602 $34,333 $33,063 $31,794 $30,525 $29,255 $27,986 $26,717 $25,447Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $483,558 $39,629 $49,565 $48,295 $47,026 $45,757 $44,487 $43,218 $41,949 $40,679 $39,410 $38,141 $36,871 $35,602 $34,333 $33,063 $31,794 $30,525 $29,255 $27,986 $26,717 $25,447Extended outage purch power, $1000sSOX $4,152 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total$4,152 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340Fixed O&M expense, $1000sFor SOX control:Maintenance (labor + mat'l) $35,519 $2,911 $2,376 $2,435 $2,496 $2,559 $2,623 $2,688 $2,755 $2,824 $2,895 $2,967 $3,041 $3,117 $3,195 $3,275 $3,357 $3,441 $3,527 $3,615 $3,706 $3,798Operating labor $12,141 $995 $812 $832 $853 $875 $896 $919 $942 $965 $990 $1,014 $1,040 $1,066 $1,092 $1,120 $1,148 $1,176 $1,206 $1,236 $1,267 $1,298For 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) $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 $0Total fixed O&M cost $47,660 $3,906 $3,188 $3,268 $3,349 $3,433 $3,519 $3,607 $3,697 $3,790 $3,884 $3,981 $4,081 $4,183 $4,288 $4,395 $4,505 $4,617 $4,733 $4,851 $4,972 $5,097Variable 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) $89,268 $7,316 $5,971 $6,121 $6,274 $6,431 $6,591 $6,756 $6,925 $7,098 $7,276 $7,457 $7,644 $7,835 $8,031 $8,232 $8,437$8,648 $8,865 $9,086 $9,313 $9,546Dibasic 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 $5,889 $483 $394 $404 $414 $424 $435 $446 $457 $468 $480 $492 $504 $517 $530 $543 $557 $570 $585 $599 $614 $630SO3reduction 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 $19,772 $1,620 $1,323 $1,356 $1,390 $1,424 $1,460 $1,496 $1,534 $1,572 $1,611 $1,652 $1,693 $1,735 $1,779 $1,823 $1,869 $1,915 $1,963 $2,012 $2,063 $2,114Gypsum 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 ($58,026) ($4,755) ($4,330) ($4,587) ($3,405) ($3,623) ($3,842) ($4,073) ($4,279) ($4,510) ($4,729) ($4,973) ($5,230) ($5,499) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782)Aux. power, energy charge $57,519 $4,714 $3,848 $3,944 $4,042 $4,143 $4,247 $4,353 $4,462 $4,574 $4,688 $4,805 $4,925 $5,048 $5,175 $5,304 $5,437 $5,572 $5,712 $5,855 $6,001 $6,151Aux. power, capacity charge $6,616 $542 $443 $454 $465 $477 $489 $501 $513 $526 $539 $553 $567 $581 $595 $610 $625 $641 $657 $673 $690 $708For 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 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Catalyst $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Water for NOX removal $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 particulate control:Bags $9,084 $744 $0 $0 $0 $0 $3,539 $0 $0 $0 $0 $4,004 $0 $0 $0 $0 $4,530 $0 $0 $0 $0 $5,125Cages $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash sales $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash landfill cost $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 $0Total variable O&M cost $130,122 $10,664 $7,648 $7,690 $9,179 $9,276 $12,918 $9,479 $9,612 $9,728 $9,866 $13,990 $10,103 $10,217 $10,327 $10,730 $15,672 $11,566 $11,999 $12,444 $12,899 $18,492Fuel expense, $1000$0 $0Total revenue requirement, $1000s$661,340 $54,198 $60,401 $59,253 $59,555 $58,465 $60,925 $56,304 $55,258 $54,197 $53,160 $56,112 $51,056 $50,002 $48,947 $48,188 $51,971 $46,707$45,987 $45,281 $44,588 $49,035Summary Revenue RequirementsNPV RR LevelizedInvestment cost $483,558 $39,629 $49,565 $48,295 $47,026 $45,757 $44,487 $43,218 $41,949 $40,679 $39,410 $38,141 $36,871 $35,602 $34,333 $33,063 $31,794 $30,525 $29,255 $27,986 $26,717 $25,447Extended outage purchased power $4,152 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340 $340Fixed O&M $47,660 $3,906 $3,188 $3,268 $3,349 $3,433 $3,519 $3,607 $3,697 $3,790 $3,884 $3,981 $4,081 $4,183 $4,288 $4,395 $4,505 $4,617 $4,733 $4,851 $4,972 $5,097Variable O&M w/o allowances or aux. pwr. $124,013 $10,163 $7,688 $7,880 $8,077 $8,279 $12,025 $8,698 $8,916 $9,138 $9,367 $13,605 $9,841 $10,087 $10,339 $10,598 $15,393 $11,134 $11,413 $11,698 $11,990 $17,415Auxiliary power, energy charge $57,519 $4,714 $3,848 $3,944 $4,042 $4,143 $4,247 $4,353 $4,462 $4,574 $4,688 $4,805 $4,925 $5,048 $5,175 $5,304$5,437 $5,572 $5,712 $5,855 $6,001 $6,151Auxiliary power, capacity charge $6,616 $542 $443 $454 $465 $477 $489 $501 $513 $526 $539 $553 $567 $581 $595 $610 $625 $641 $657 $673 $690 $708Allowances ($58,026) ($4,755) ($4,330) ($4,587) ($3,405) ($3,623) ($3,842) ($4,073) ($4,279) ($4,510) ($4,729) ($4,973) ($5,230) ($5,499) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782) ($5,782)Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $665,493 $54,539 $60,741 $59,594 $59,895 $58,806 $61,265 $56,644 $55,598 $54,537 $53,500 $56,452 $51,396 $50,342 $49,287 $48,528 $52,311 $47,048 $46,328 $45,621 $44,929 $49,376Case 13: Dry FGD0.7% Sulfur Fuel, Unit 1Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/7/2008, 12:54 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 Year2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032Discount 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) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158) (2,158)Equivalent SOX allowances sold(+)/bought(-) 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,819 12,81912,819 12,819 12,819 12,819 12,819 12,819Tons SOX removed41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003 41,003Available Hg allowances, oz. 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 1,201 1,201Hg allowance surrender rate 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 2.5305 2.5305Equivalent available Hg allowances, oz. 2,984 2,984 3,047 3,047 3,047 3,047 3,047 475 475 475 475 475 475 475 475 475 475 475 475 475Hg allowances used, oz. (i.e., emissions) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699) (10,699)Hg allowances sold(+)/bought(-) (4,730) (4,730) (4,604) (4,604) (4,604) (4,604) (4,604) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021) (9,021)Ounces Hg removed00000000000000000000Tons NOX removed00000000000000000000Tons particulates removed00000000000000000000SOX allowance cost, $/ton (escalated values) $337 $357 $265 $282 $299 $317 $333 $351 $368 $387 $407 $428 $450 $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 $492,774 $40,384 $50,509 $49,216 $47,922 $46,629 $45,335 $44,042 $42,748 $41,455 $40,161 $38,868 $37,574 $36,280 $34,987 $33,693 $32,400 $31,106 $29,813 $28,519 $27,226 $25,932Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $492,774 $40,384 $50,509 $49,216 $47,922 $46,629 $45,335 $44,042 $42,748 $41,455 $40,161 $38,868 $37,574 $36,280 $34,987 $33,693 $32,400 $31,106 $29,813 $28,519 $27,226 $25,932Extended outage purch power, $1000sSOX $4,371 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Particulates $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total$4,371 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358Fixed O&M expense, $1000sFor SOX control:Maintenance (labor + mat'l) $35,519 $2,911 $2,376 $2,435 $2,496 $2,559 $2,623 $2,688 $2,755 $2,824 $2,895 $2,967 $3,041 $3,117 $3,195 $3,275 $3,357 $3,441 $3,527 $3,615 $3,706 $3,798Operating labor $12,141 $995 $812 $832 $853 $875 $896 $919 $942 $965 $990 $1,014 $1,040 $1,066 $1,092 $1,120 $1,148 $1,176 $1,206 $1,236 $1,267 $1,298For 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) $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 $0Total fixed O&M cost $47,660 $3,906 $3,188 $3,268 $3,349 $3,433 $3,519 $3,607 $3,697 $3,790 $3,884 $3,981 $4,081 $4,183 $4,288 $4,395 $4,505 $4,617 $4,733 $4,851 $4,972 $5,097Variable 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) $90,541 $7,420 $6,056 $6,208 $6,363 $6,522 $6,685 $6,852 $7,024 $7,199 $7,379 $7,564 $7,753 $7,947 $8,145 $8,349 $8,558$8,772 $8,991 $9,216 $9,446 $9,682Dibasic 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 $6,088 $499 $407 $417 $428 $439 $450 $461 $472 $484 $496 $509 $521 $534 $548 $561 $575 $590 $605 $620 $635 $651SO3reduction 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 $20,054 $1,643 $1,341 $1,375 $1,409 $1,445 $1,481 $1,518 $1,556 $1,595 $1,634 $1,675 $1,717 $1,760 $1,804 $1,849 $1,895 $1,943 $1,991 $2,041 $2,092 $2,144Gypsum 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 ($57,890) ($4,744) ($4,320) ($4,576) ($3,397) ($3,615) ($3,833) ($4,064) ($4,269) ($4,499) ($4,717) ($4,961) ($5,217) ($5,487) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769)Aux. power, energy charge $57,519 $4,714 $3,848 $3,944 $4,042 $4,143 $4,247 $4,353 $4,462 $4,574 $4,688 $4,805 $4,925 $5,048 $5,175 $5,304 $5,437 $5,572 $5,712 $5,855 $6,001 $6,151Aux. power, capacity charge $6,616 $542 $443 $454 $465 $477 $489 $501 $513 $526 $539 $553 $567 $581 $595 $610 $625 $641 $657 $673 $690 $708For 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 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Catalyst $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Water for NOX removal $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 particulate control:Bags $9,084 $744 $0 $0 $0 $0 $3,539 $0 $0 $0 $0 $4,004 $0 $0 $0 $0 $4,530 $0 $0 $0 $0 $5,125Cages $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash sales $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Flyash landfill cost $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 $0Total variable O&M cost $132,013 $10,819 $7,775 $7,821 $9,311 $9,410 $13,057 $9,621 $9,758 $9,878 $10,020 $14,148 $10,266 $10,384 $10,498 $10,905 $15,852 $11,749 $12,187 $12,636 $13,096 $18,693Fuel expense, $1000$0 $0Total revenue requirement, $1000s$672,447 $55,109 $61,473 $60,305 $60,582 $59,472 $61,911 $57,270 $56,204 $55,122 $54,065 $56,997 $51,921 $50,847 $49,773 $48,993 $52,756 $47,473$46,733 $46,006 $45,294 $49,722Summary Revenue RequirementsNPV RR LevelizedInvestment cost $492,774 $40,384 $50,509 $49,216 $47,922 $46,629 $45,335 $44,042 $42,748 $41,455 $40,161 $38,868 $37,574 $36,280 $34,987 $33,693 $32,400 $31,106 $29,813 $28,519 $27,226 $25,932Extended outage purchased power $4,371 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358 $358Fixed O&M $47,660 $3,906 $3,188 $3,268 $3,349 $3,433 $3,519 $3,607 $3,697 $3,790 $3,884 $3,981 $4,081 $4,183 $4,288 $4,395 $4,505 $4,617 $4,733 $4,851 $4,972 $5,097Variable O&M w/o allowances or aux. pwr. $125,767 $10,307 $7,805 $8,000 $8,200 $8,405 $12,154 $8,831 $9,052 $9,278 $9,510 $13,751 $9,991 $10,241 $10,497 $10,759 $15,558 $11,304 $11,587 $11,876 $12,173 $17,603Auxiliary power, energy charge $57,519 $4,714 $3,848 $3,944 $4,042 $4,143 $4,247 $4,353 $4,462 $4,574 $4,688 $4,805 $4,925 $5,048 $5,175 $5,304$5,437 $5,572 $5,712 $5,855 $6,001 $6,151Auxiliary power, capacity charge $6,616 $542 $443 $454 $465 $477 $489 $501 $513 $526 $539 $553 $567 $581 $595 $610 $625 $641 $657 $673 $690 $708Allowances ($57,890) ($4,744) ($4,320) ($4,576) ($3,397) ($3,615) ($3,833) ($4,064) ($4,269) ($4,499) ($4,717) ($4,961) ($5,217) ($5,487) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769) ($5,769)Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $676,818 $55,467 $61,831 $60,663 $60,941 $59,831 $62,269 $57,628 $56,562 $55,481 $54,423 $57,355 $52,279 $51,205 $50,131 $49,351 $53,114 $47,831 $47,091 $46,364 $45,652 $50,080Case 14: Dry FGD0.7% Sulfur Fuel, Unit 2Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/7/2008, 12:55 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 spray dryer absorber FGD system on Gerald Gentleman Station, Units 1 & 2.

Scope includes:

• Unit 1 Spray Dryer Absorber Area

• Unit 2 Spray Dryer Absorber Area

• Units 1&2 Common Areas (Reagent Prep and handling, recycle and waste handling)

• 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.

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.

### Nebraska Public Power District

General Gentleman Station, Units 1&2 Project No. 12194-001

2/7/2008

Page 2 of 2 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

Page 1 of 5 

# Technical Basis

The following is a summary of the technical basis of the Phase 1 spray dryer absorber

FGD system capital cost estimate and the Unit 1 and 2 ID Fan and Aux Power system

capital cost estimate.

1. Lime Handling common to both Units

a. Lime rail car unloader

i. Lime will be brought on site as a 128 car unit train

ii. The unloading system will unload a car in 1.5 hrs. The station will be

able to unload in 16-20 worki ng days, using one 12 hour shift

iii. The system will consist of vacuum pneumatic equipment to unload the

rail car through the three hoppers.

iv. Rail car unloading building

v. Three (3) vacuum systems operate (one per rail car hopper) to unload a

car in 1.5 hrs

vi. Blowers

vii. Dust control using ventilati on system and dust collector

viii. Blower building

ix. Vendor quote from Chicago Conveyor Corp

b. Lime storage silo

i. Concrete Silo

ii. Two silos, 14 day storage per Unit and capable of storing a unit train

of lime, 4 days spare capac ity, 12,800 tons storage total

iii. Diameter (60’) and he ight (145’) to top

iv. 7,500 ton storage each

v. Concrete silo with bin vent for dust control

vi. Two hopper outlet

vii. Vendor quote from Chicago Conveyor Corp

c. Lime transfer systems

i. From silo to lime prep day bins

ii. Pneumatic, pressurized, two 750 lineal feet of pipe

iii. Pneumatic transport piping located on an above grade pipe rack

iv. Vendor quote from Chicago Conveyor Corp

2. Lime Preparation per Unit

a. Two (2) ball mill lime slakers at 100% capacity, each with a grit screen,

gravimetric feeder

b. Two (2) lime transfer tanks

c. Two (2) lime slurry storage tanks

d. Two (2) slurry feed centrifugal pumps

e. Two(2) slurry transfer centrifugal pumps

f. Lime day bin

g. Lime prep building, 60 x 100 x 125 ft

f. Vendor quote from B&W and Alstom

## Nebraska Public Power Dist rict Project No, 12194-001

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

Page 2 of 5 3. Absorber Area per Unit

a. Three (3) absorber vessels per unit, with access doors

b. Rotary atomizers or dual fluid nozzles, spare atomizer included

c. Vessel material carbon steel, 1⁄4 in. – 5/8 in. carbon steel

d. Penthouse enclosure

e. 6” insulation with lagging

f. Heating and ventilation

g. Vacuum piping

h. Vendor quote from B&W and Alstom

i. B&W was contacted to determine if tw o SDA modules could be installed in

lieu of three. Due to the high gas fl ow rate, B&W stated that two SDAs

would not feasible.

4. Recycle Area per Unit

a. One (1) recycle storage silo

b. Two (2) recycle mix tanks

c. Two (2) recycle slurry tanks each with two (2) recycle slurry centrifugal

pumps per tank

d. Agitators for each tank

e. Vendor quote from B&W and Alstom

5. Baghouse Ash Handling System common to both Units

a. Modifications of existing pipe and blowers

b. Addition of two (2) new 3-day storage flya sh silos located near track for truck

or rail loading, 222,730 ft 3 

## of active storage total; 58’ diameter

c. Addition of two (2) new 4-hour intermed iate silos located near the crusher

building. These are separate from the recycle silos.

d. Addition of two (2) new pressure conv eying systems from the intermediate

silos to the flyash silos

e. Silos have damp unloading at silo exit and bin vent filters

f. Vendor quote from Allen-Sherman-Hoff

6. Flues including support steel per Unit

a. Air Heater outlet to absorber inlet

i. Carbon steel, 1⁄4 in.

ii. Velocity = 4000 to 4500 fpm

iii. 6” insulation with lagging

b. Absorber outlet to baghouse inlet

i. Carbon steel, 1⁄4 in.

ii. Velocity 4000 fpm

iii. 6” insulation with lagging

c. ID Fan outlet to new booster ID fan

i. Carbon steel, 1⁄4 in.

ii. 4000 fpm

iii. 4” insulation with lagging

## Nebraska Public Power Dist rict Project No, 12194-001

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

Page 3 of 5 d. Flue path reinforcement

i. Reinforce baghouse outlet header duct

e. Completion of Unit 2 hot duct incl uding expansion joints and insulation and

lagging.

7. Control System Modifications per Unit

a. Based on number of I/O points. Ap proximately 1,004 per Unit including

SDA’s and reagent prep. The co mmon area will need approx. 2,000 I/O

points. The dry FGD will have approx. 4,000 I/O points total.

8. Rail Yard Extension common to both Units

a. Use NPPD’s planned phase 2 additional rail loop to receive a unit train once

per month

b. Extend the rail spur to the west to allow the unit train to be unloaded and cars

to be stored on site.

c. Add three ladder tracks to hold a unit train (128 cars)

9. Subsurface and Foundation Work- All

a. Foundation system consists of drilled caissons

10. Civil Work- All

a. Roads.

b. White rock surfacing.

11. Construction Work- All

a. Union labor

b. Premiums and per diems included

c. Outage time at two 12 hour shifts, included in the project manhours and

premium time

12. Pipe Racks common to both Units

a. Between lime unloading and lime silo

b. Between lime silo, reagent prep and fly ash silos

13. Chimney per Unit

a. Put trowel coating on top 50 ft. of inside of each chimney liner to help with

condensation

16. Baghouse Modifications per Unit

a. Reverse the inlet plenum so that th e direction of the inle t flow is now from

the rear of the baghouse

b. Add hopper heaters at 13 kW per hopper

c. Relocate the reverse gas duct and platforms

d. Expect the baghouse to operate at 1-2” w.c. greater pressure drop with dry

FGD ahead of baghouse

e. Reinforce the baghouse outlet header, approx. 30 tons

## Nebraska Public Power Dist rict Project No, 12194-001

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

Page 4 of 5 f. Reinforce baghouse struct ure for increased pressure drop.

g. Includes removal and inst allation of insu lation and lagging

f. Vendor input from Siemens (WAPC)

17. Demolition and Relocation

a. Demolition of warehouse east of Unit 2 baghouse and addition of new

warehouse next to GGS main plant warehouse.

b. Demolition of existing fly ash silos

c. Demolition of existing four hydrobins

d. Demolition of existing air heater to baghouse inlet duct would cost approx.

$1,860,000 per Unit.

18. CEMS per Unit

a. No change, use existing CEMS in chimney

19. Water Treatment common to both Units

a. None included. Water having less than 200 mg/L sulfat e content is good and

less than 500 mg/L is acceptable. Sutherland Reservoir and well water have less

than 200 mg/L so no treatment is necessary.

b. An in-line water heater is incl uded because slaking water needs to be

between 50degF and 90degF to sustain good slaking.

20. Instrument air compressor and dryer common to both Units

a. Air Compressors; 2 x 100%, 250 scfm ea. @ 100 psig

b. IA dryers w/filters; 2 x 100%, 250 net scfm ea

21. Field Painting – All

a. Multiple coat system used for exposed ductwork only.

b. Inorganic zinc primer a nd polyurethane system used for steel.

22. Performance Testing- All

a. Part of Owner’s costs

23. Construction Support- All

a. 12 months, 1.5 persons

24. Piping per Unit

a. Instrument air piping to ev ery silo or day bin, bin vent and reagent

preparation/recycle area

b. Heat traced piping

25. Installation- All

a. Included

26. New booster ID fans-All

## Nebraska Public Power Dist rict Project No, 12194-001

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

Page 5 of 5 a. Two 10,000 hp axial ID fans per Unit. Duplicate of the existing ID fans.

These fans are sized to overcome pressu re drop associated with both an SCR and

FGD. If only one system is insta lled, the hp and price can be reduced.

b. Includes foundations and motors. No spare motor is included.

c. Vendor quote from TLT Babcock.

27. 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, r ecycle, spray dryer absorber and SCR.

e. One reagent prep electrical equipment building.

f. Two transformer elect rical equipment building.

g. Two main electrical equipment buildi ng located north of Unit 1 and south of

Unit 2 baghouses.Nebraska Public Power DistrictGerald Gentleman Station Unit 1 & 2Estimate Summaryfor Dry FGD12194-0012/7/2008Equipment Cost($ Millions)Material Cost($ Millions)Labor Cost($ Millions)Erection LaborMan-HoursTotal Cost($ Millions)Normalized Cost($/kW)Unit 1 Absorber Area (Estimate No. 229934B)Direct 27.501 29.947 91.554 728,726 149.002EPC portion 0.000 0.000 29.800 0 29.800Indirect 0.000 0.000 0.000 0 3.573Escalation 0.000 0.000 0.000 0 33.071Sales/Use Tax 0.000 0.000 0.000 0 3.160AFUDC 0.000 0.000 0.000 0 21.889Contingency @ 20% 0.000 0.000 0.000 0 43.089283.584Unit 2 Absorber Area (Estimate No. 22999B)Direct 27.501 30.109 92.808 742,964 150.418EPC portion 0.000 0.000 30.084 0 30.084Indirect 0.000 0.000 0.000 0 3.610Escalation 0.000 0.000 0.000 0 35.590Sales/Use Tax 0.000 0.000 0.000 0 3.169AFUDC 0.000 0.000 0.000 0 25.989Contingency @ 20% 0.000 0.000 0.000 0 43.940292.800Unit 1 & 2 Common Area (Estimate No. 22994B)Direct 36.534 23.074 67.784 653,986 127.392EPC portion 0.000 0.000 30.754 0 30.754Indirect 0.000 0.000 0.000 0 39.101Escalation 0.000 0.000 0.000 0 40.232Sales/Use Tax 0.000 0.000 0.000 0 3.278AFUDC 0.000 0.000 0.000 0 26.973Contingency @ 20% 0.000 0.000 0.000 0 47.496315.226Unit 1 & 2 Auxil. Power & ID Fans (Estimate No. 22998B)Direct 21.495 5.228 21.925 252,640 48.648EPC portion 0.000 0.000 9.729 0 9.729Indirect 0.000 0.000 0.000 0 1.168Escalation 0.000 0.000 0.000 0 11.556Sales/Use Tax 0.000 0.000 0.000 0 1.470AFUDC 0.000 0.000 0.000 0 8.451Contingency @ 20% 0.000 0.000 0.000 0 14.22095.242Project TotalsDirect 113.031 88.358 274.071 2,378,316 475.460EPC portion 0.000 0.000 100.367 0 100.367Indirect 0.000 0.000 0.000 0 47.452Escalation 0.000 0.000 0.000 0 120.449Sales/Use Tax 0.000 0.000 0.000 0 11.077AFUDC 0.000 0.000 0.000 0 83.302Contingency @ 20% 0.000 0.000 0.000 0 148.745"All In" Grand Total with EPC Fee = 986.852 658Grand Total without EPC Fee = 886.485 591Price Level = Q4, 2007Page 1 of 1A 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 DRY FGD SYSTEM- OPTION 1 GENERAL ARRANGEMENT

MS-DRYFGD01

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.

10-08-2007 D.SKOIRCHET D.G.SLOAT

-------- A

B 11-21-2007 D.SKOIRCHET D.G.SLOAT

-------- FILENAME:MSDRYFGD0101.DGN

DESIGN FREEZE FOR COMMENTS 1"=100’ 2 1

6

7

0’ 100’ 100’ 200’ 300’ 400’ 8 9 10

3 3 5 11 12 13

14

15 16 17 18

19 20 21



# NORTH 27 28 29

30

31

32 34 35

EXISTING STRUCTURES KEY:

1. UNIT 1

2. UNIT 2

3. PRECIPITATOR (ABANDONED)

4. CHIMNEY

5. BAGHOUSE

6. SERVICE

7. ADMINISTRATION BUILDING

8. FUEL OIL PUMP HOUSE

9. FUEL OIL TANKS

10. HVAC COOLING TOWERS

11. SEWAGE TREATMENT PLANT

12. NEUTRALIZATION BASIN 22

22

26 25 23 24

13. CHEMICAL BUILDING

14. OIL WATER SEPARATOR

15. FLY ASH SILO

16. DEWATERING BIN (ABANDONED)

17. HYDRO BIN (ABANDONED)

18. ASH WATER MAKE-UP TANK (ABANDONED)

19. ASH WATER SURGE TANK

20. ASH WATER SETTLING TANK (ABANDONED)

21. BOTTOM ASH PUMPHOUSE

22. WAREHOUSE

23. WASTE DISPOSAL

24. MOBILE MAINTENANCE 25. BREAK BUILDING

26. TRAINING/SAFETY BUILDING

27. ROTARY COAL CAR DUMPER BUILDING

28. COAL UNLOADING CONVEYORS A-C & B-C

29. TRANSFER BUILDING

30. STACKOUT/RECLAIM BUILDING

31. RECLAIM CONEYORS A-C & B-C

32. CRUSHER BUILDING

33. PLANT CONVEYORS A-C & B-C

34. EMERGENCY RECLAIM HOPPER

35. RECLAIM TRANSFER BUILDING

36. YARD CONVEYOR A-C 36

33 D

A B

A B



## PLAN

RAIL KEY:

EXISTING

PROPOSED NPPD ADDITIONS

NEW LIMESTONE UNLOADING 4 4 C F

C E G

H

J

K K

NEW STRUCTURES KEY:

A. ABSORBER TOWER

B. REAGENT PREPARATION BUILDING

C. DAY SILO

D. LIME RAIL CAR UNLOADING

E. LIME CONVEYOR PIPE RACK

F. LIME STORAGE SILO

G. LIME TRUCK UNLOADING

H. LIME RAIL CAR SIDING

J. FLY ASH SILO (RELOCATED)

K. ELECTRICAL BUILDING

L. WAREHOUSE

M. RESERVE SPACE FOR BOOSTER FAN

N. RESERVE SPACE FOR CO2 RECOVERY SYSTEM M M M

N N 

### MATCH LINE A-A

MATCH LINE A-A NOTES:

1. BAGHOUSE INLET PLENUMS REVERSED; INLET

DUCT CONNECTION MOVED TO EAST SIDE.

2. BAGHOUSE REVERSE AIR DUCTS ON EAST SIDE

OF BAGHOUSE TO BE RAISED TO PROVIDE CLEARANCE

FOR NEW DUCTS FROM ABSORBER TOWERS.

3. EXISTING TWO FLY ASH SILOS (ITEM 15) TO BE

RELOCATED TO THE SOUTH (NEW ITEM J).

4. EXISTING ABANDONED DEWATERING BINS (ITEM

16) AND HYDRO BINS (ITEM 17) TO BE DEMOLISHED.

5. THE ELEVATED AREA OF THE EXISTING FLY ASH

SILOS, DEWATERING BINS AND HYDRO BINS AND

ASSOCIATED APPROACH ROADS TO BE REMOVED.

6. WAREHOUSE EAST OF THE UNIT 2 BAGHOUSE

DEMOLISHED OR RELOCATED.

7. ROADS IN AREA OF ABORBER TOWERS/REAGENT

PREPARATION BUILDINGS REWORKED 

## PARTIAL PLAN

22 22 L H