# WET 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 Absorber Area (Estimate No. 22987B)

- Unit 2 Absorber Area (Estimate No. 22997B)

- Units 1&2 Common (Estimate No. 22988B)

- Auxiliary Power and Booster ID Fans (Estimate No. 22995B)

General Arrangement of Wet FGD

Color 3-D General Arrangement of Wet FGD (New Equipment in Teal)Wet Flue Gas DesulphurizationCapital and O&M CostsGGS Unit 1 GGS Unit 2 Common Facilities Auxiliary Power/ID Fans TOTAL STATIONCapital CostsAbsorber Area 62,436,000$ 62,436,000$ -$ -$ 124,872,000$Civil/SiteWork 1,325,000$ 1,325,000$ -$ -$ 2,650,000$Flue Gas System/Ductwork 46,051,000$ 46,051,000$ -$ -$ 92,102,000$Reagent Preparation System -$ -$ 24,900,000$ -$ 24,900,000$Dewatering System -$ -$ 19,866,000$ -$ 19,866,000$Common Structures/Buildings -$ -$ 42,981,000$ -$ 42,981,000$Reagent Handling System -$ -$ 12,124,000$ -$ 12,124,000$Gypsum Handling Modifications -$ -$ 7,101,000$ -$ 7,101,000$Track Ladders and Switches -$ -$ 2,604,000$ -$ 2,604,000$Track System Mods- Phase 2 -$ -$ 4,539,000$ -$ 4,539,000$Maintenance Equipment -$ -$ 2,832,000$ -$ 2,832,000$Miscellaneous Mechanical Items 1,408,000$ 1,408,000$ 7,066,000$ -$ 9,882,000$Pipe Rack 2,335,000$ 2,335,000$ -$ -$ 4,670,000$Booster Fans -$ -$ -$ 12,206,000$ 12,206,000$Instrumentation and Controls -$ -$ 5,315,000$ -$ 5,315,000$Electrical Modifications -$ -$ -$ 27,364,000$ 27,364,000$Mobilization/Demobilization - 1% of Labor 439,000$ 439,000$ 536,000$ 151,000$ 1,565,000$Cost Due to Overtime - 5-10's 5,885,000$ 5,885,000$ 7,196,000$ 2,022,000$ 20,988,000$Per Diem 5,327,000$ 5,327,000$ 7,564,000$ 2,841,000$ 21,059,000$Spare Parts - 3% of Equipment 1,656,000$ 1,656,000$ 1,555,000$ 577,000$ 5,444,000$Freight 3,568,000$ 3,568,000$ 3,864,000$ 1,254,000$ 12,254,000$General & Administration - 5% of Material and Labor 3,213,000$ 3,213,000$ 4,234,000$ 1,118,000$ 11,778,000$Profit - 10% of Material and Labor 6,426,000$ 6,426,000$ 8,469,000$ 2,237,000$ 23,558,000$EPC Fee - 20% of Total Cost 28,014,000$ 28,014,000$ 39,091,000$ 9,954,000$ 105,073,000$Subtotal168,083,000$ 168,083,000$ 201,837,000$ 59,724,000$ 597,727,000$Other CostsIndirect 3,362,000$ 3,362,000$ 44,045,000$ 1,194,000$ 51,963,000$Escalation 31,288,000$ 33,446,000$ 50,232,000$ 11,882,000$ 126,848,000$Sales/Use Tax 4,241,000$ 4,241,000$ 4,660,000$ 1,492,000$ 14,634,000$Contingency 40,547,000$ 40,978,000$ 59,223,000$ 14,560,000$ 155,308,000$AFUDC 20,699,000$ 24,354,000$ 34,894,000$ 8,652,000$ 88,599,000$Subtotal100,137,000$ 106,381,000$ 193,054,000$ 37,780,000$ 437,352,000$Total Capital Cost268,220,000$ 274,464,000$ 394,891,000$ 97,504,000$ 1,035,079,000$Levelized Capital Cost-- -- -- -- 84,827,000$Total Capital Cost (w/ fan sized for FGD only)-- -- -- 92,244,000$ 1,029,819,000$Levelized Capital Cost (w/ fan sized for FGD only)-- -- -- -- 83,965,000$O&M CostsLevelized Fixed O&M -- -- -- -- 10,540,000$Levelized Variable O&M -- -- -- -- 13,945,000$Levelized O&M Cost-- -- -- -- 24,485,000$Levelized Outage Cost-- -- -- -- -$Total Levelized Capital, Outage and O&M Cost-- -- -- -- 108,450,000$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) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216) (1,216)Equivalent SOX allowances sold(+)/bought(-) 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,761 13,76113,761 13,761 13,761 13,761 13,761 13,761Tons SOX removed41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338 41,338Available 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 removed 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358 113,358SOX 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 $509,158 $41,727 $52,189 $50,852 $49,516 $48,179 $46,842 $45,506 $44,169 $42,833 $41,496 $40,160 $38,823 $37,487 $36,150 $34,814 $33,477 $32,141 $30,804 $29,467 $28,131 $26,794Hg $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 $509,158 $41,727 $52,189 $50,852 $49,516 $48,179 $46,842 $45,506 $44,169 $42,833 $41,496 $40,160 $38,823 $37,487 $36,150 $34,814 $33,477 $32,141 $30,804 $29,467 $28,131 $26,794Extended 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 $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$0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fixed O&M expense, $1000sFor SOX control:Maintenance (labor + mat'l) $50,742 $4,158 $3,394 $3,479 $3,566 $3,655 $3,747 $3,840 $3,936 $4,035 $4,136 $4,239 $4,345 $4,454 $4,565 $4,679 $4,796 $4,916 $5,039 $5,165 $5,294 $5,426Operating labor $13,569 $1,112 $908 $930 $954 $977 $1,002 $1,027 $1,053 $1,079 $1,106 $1,134 $1,162 $1,191 $1,221 $1,251 $1,283 $1,315 $1,347 $1,381 $1,416 $1,451For 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 $64,311 $5,270 $4,302 $4,409 $4,520 $4,633 $4,748 $4,867 $4,989 $5,114 $5,241 $5,372 $5,507 $5,644 $5,786 $5,930 $6,078 $6,230 $6,386 $6,546 $6,710 $6,877Variable O&M expense, $1000sFor SOX control:Limestone $32,746 $2,684 $2,190 $2,245 $2,301 $2,359 $2,418 $2,478 $2,540 $2,604 $2,669 $2,736 $2,804 $2,874 $2,946 $3,020 $3,095 $3,172 $3,252 $3,333 $3,416 $3,502Lime (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 $7,204 $590 $482 $494 $506 $519 $532 $545 $559 $573 $587 $602 $617 $632 $648 $664 $681 $698 $715 $733 $752 $770SO3reduction 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 $11,331 $929 $758 $777 $796 $816 $837 $858 $879 $901 $923 $947 $970 $994 $1,019 $1,045 $1,071 $1,098 $1,125 $1,153 $1,182 $1,212Purchases (+) or sales (-) of allowances ($62,144) ($5,093) ($4,638) ($4,913) ($3,647) ($3,881) ($4,115) ($4,362) ($4,582) ($4,830) ($5,064) ($5,326) ($5,601) ($5,890) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193)Aux. power, energy charge $85,494 $7,006 $5,719 $5,862 $6,008 $6,159 $6,313 $6,470 $6,632 $6,798 $6,968 $7,142 $7,321 $7,504 $7,691 $7,884 $8,081 $8,283 $8,490 $8,702 $8,920 $9,142Aux. power, capacity charge $9,834 $806 $658 $674 $691 $708 $726 $744 $763 $782 $802 $822 $842 $863 $885 $907 $930 $953 $977 $1,001 $1,026 $1,052For 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 $4,758 $390 $0 $0 $0 $0 $0 $0 $3,718 $0 $0 $0 $0 $0 $0 $4,419 $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 ($1,294) ($106) ($87) ($89) ($91) ($93) ($96) ($98) ($100) ($103) ($105) ($108) ($111) ($114) ($116) ($119) ($122) ($125) ($129) ($132) ($135) ($138)Flyash landfill cost $4,793 $393 $321 $329 $337 $345 $354 $363 $372 $381 $391 $400 $410 $421 $431 $442 $453 $464 $476 $488 $500 $513Aux. 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 $92,722 $7,599 $5,404 $5,379 $6,903 $6,933 $6,969 $6,998 $10,780 $7,106 $7,170 $7,214 $7,253 $7,285 $7,312 $12,069 $7,995 $8,350 $8,714 $9,086 $9,468 $9,860Fuel expense, $1000$0 $0Total revenue requirement, $1000s$666,190 $54,596 $61,894 $60,641 $60,938 $59,744 $58,560 $57,371 $59,938 $55,052 $53,908 $52,747 $51,583 $50,416 $49,247 $52,812 $47,551 $46,721$45,904 $45,100 $44,309 $43,531Summary Revenue RequirementsNPV RR LevelizedInvestment cost $509,158 $41,727 $52,189 $50,852 $49,516 $48,179 $46,842 $45,506 $44,169 $42,833 $41,496 $40,160 $38,823 $37,487 $36,150 $34,814 $33,477 $32,141 $30,804 $29,467 $28,131 $26,794Extended outage purchased power $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fixed O&M $64,311 $5,270 $4,302 $4,409 $4,520 $4,633 $4,748 $4,867 $4,989 $5,114 $5,241 $5,372 $5,507 $5,644 $5,786 $5,930 $6,078 $6,230 $6,386 $6,546 $6,710 $6,877Variable O&M w/o allowances or aux. pwr. $59,538 $4,879 $3,664 $3,756 $3,850 $3,946 $4,045 $4,146 $7,967 $4,356 $4,465 $4,576 $4,691 $4,808 $4,928 $9,471 $5,178 $5,307 $5,440 $5,576 $5,715 $5,858Auxiliary power, energy charge $85,494 $7,006 $5,719 $5,862 $6,008 $6,159 $6,313 $6,470 $6,632 $6,798 $6,968 $7,142 $7,321 $7,504 $7,691 $7,884$8,081 $8,283 $8,490 $8,702 $8,920 $9,142Auxiliary power, capacity charge $9,834 $806 $658 $674 $691 $708 $726 $744 $763 $782 $802 $822 $842 $863 $885 $907 $930 $953 $977 $1,001 $1,026 $1,052Allowances ($62,144) ($5,093) ($4,638) ($4,913) ($3,647) ($3,881) ($4,115) ($4,362) ($4,582) ($4,830) ($5,064) ($5,326) ($5,601) ($5,890) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193) ($6,193)Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $666,190 $54,596 $61,894 $60,641 $60,938 $59,744 $58,560 $57,371 $59,938 $55,052 $53,908 $52,747 $51,583 $50,416 $49,247 $52,812 $47,551 $46,721 $45,904 $45,100 $44,309 $43,531Case 11: Wet FGD0.7% Sulfur Fuel, Unit 1Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/7/2008, 12:53 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) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295) (1,295)Equivalent SOX allowances sold(+)/bought(-) 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,682 13,68213,682 13,682 13,682 13,682 13,682 13,682Tons SOX removed41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866 41,866Available 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 removed 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970 114,970SOX 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 $515,402 $42,238 $52,829 $51,476 $50,123 $48,770 $47,417 $46,064 $44,711 $43,358 $42,005 $40,652 $39,299 $37,946 $36,594 $35,241 $33,888 $32,535 $31,182 $29,829 $28,476 $27,123Hg $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 $515,402 $42,238 $52,829 $51,476 $50,123 $48,770 $47,417 $46,064 $44,711 $43,358 $42,005 $40,652 $39,299 $37,946 $36,594 $35,241 $33,888 $32,535 $31,182 $29,829 $28,476 $27,123Extended 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 $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$0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fixed O&M expense, $1000sFor SOX control:Maintenance (labor + mat'l) $50,742 $4,158 $3,394 $3,479 $3,566 $3,655 $3,747 $3,840 $3,936 $4,035 $4,136 $4,239 $4,345 $4,454 $4,565 $4,679 $4,796 $4,916 $5,039 $5,165 $5,294 $5,426Operating labor $13,569 $1,112 $908 $930 $954 $977 $1,002 $1,027 $1,053 $1,079 $1,106 $1,134 $1,162 $1,191 $1,221 $1,251 $1,283 $1,315 $1,347 $1,381 $1,416 $1,451For 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 $64,311 $5,270 $4,302 $4,409 $4,520 $4,633 $4,748 $4,867 $4,989 $5,114 $5,241 $5,372 $5,507 $5,644 $5,786 $5,930 $6,078 $6,230 $6,386 $6,546 $6,710 $6,877Variable O&M expense, $1000sFor SOX control:Limestone $33,213 $2,722 $2,222 $2,277 $2,334 $2,393 $2,452 $2,514 $2,576 $2,641 $2,707 $2,775 $2,844 $2,915 $2,988 $3,063 $3,139 $3,218 $3,298 $3,381 $3,465 $3,552Lime (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 $7,460 $611 $499 $512 $524 $537 $551 $565 $579 $593 $608 $623 $639 $655 $671 $688 $705 $723 $741 $759 $778 $798SO3reduction 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 $11,492 $942 $769 $788 $808 $828 $849 $870 $891 $914 $937 $960 $984 $1,009 $1,034 $1,060 $1,086 $1,113 $1,141 $1,170 $1,199 $1,229Purchases (+) or sales (-) of allowances ($61,788) ($5,064) ($4,611) ($4,885) ($3,626) ($3,858) ($4,091) ($4,337) ($4,556) ($4,802) ($5,035) ($5,295) ($5,569) ($5,856) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157)Aux. power, energy charge $85,494 $7,006 $5,719 $5,862 $6,008 $6,159 $6,313 $6,470 $6,632 $6,798 $6,968 $7,142 $7,321 $7,504 $7,691 $7,884 $8,081 $8,283 $8,490 $8,702 $8,920 $9,142Aux. power, capacity charge $9,834 $806 $658 $674 $691 $708 $726 $744 $763 $782 $802 $822 $842 $863 $885 $907 $930 $953 $977 $1,001 $1,026 $1,052For 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 $4,758 $390 $0 $0 $0 $0 $0 $0 $3,718 $0 $0 $0 $0 $0 $0 $4,419 $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 ($1,313) ($108) ($88) ($90) ($92) ($95) ($97) ($99) ($102) ($104) ($107) ($110) ($112) ($115) ($118) ($121) ($124) ($127) ($130) ($134) ($137) ($140)Flyash landfill cost $4,861 $398 $325 $333 $342 $350 $359 $368 $377 $387 $396 $406 $416 $427 $437 $448 $459 $471 $483 $495 $507 $520Aux. 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 $94,013 $7,705 $5,493 $5,472 $6,989 $7,022 $7,062 $7,094 $10,879 $7,208 $7,275 $7,323 $7,365 $7,401 $7,431 $12,190 $8,119 $8,476 $8,842 $9,217 $9,601 $9,995Fuel expense, $1000$0 $0Total revenue requirement, $1000s$673,725 $55,213 $62,623 $61,357 $61,632 $60,425 $59,227 $58,025 $60,579 $55,679 $54,522 $53,348 $52,171 $50,992 $49,810 $53,361 $48,085 $47,241$46,410 $45,592 $44,787 $43,995Summary Revenue RequirementsNPV RR LevelizedInvestment cost $515,402 $42,238 $52,829 $51,476 $50,123 $48,770 $47,417 $46,064 $44,711 $43,358 $42,005 $40,652 $39,299 $37,946 $36,594 $35,241 $33,888 $32,535 $31,182 $29,829 $28,476 $27,123Extended outage purchased power $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Fixed O&M $64,311 $5,270 $4,302 $4,409 $4,520 $4,633 $4,748 $4,867 $4,989 $5,114 $5,241 $5,372 $5,507 $5,644 $5,786 $5,930 $6,078 $6,230 $6,386 $6,546 $6,710 $6,877Variable O&M w/o allowances or aux. pwr. $60,472 $4,956 $3,727 $3,820 $3,916 $4,013 $4,114 $4,217 $8,040 $4,430 $4,541 $4,654 $4,771 $4,890 $5,012 $9,557 $5,266 $5,398 $5,533 $5,671 $5,813 $5,958Auxiliary power, energy charge $85,494 $7,006 $5,719 $5,862 $6,008 $6,159 $6,313 $6,470 $6,632 $6,798 $6,968 $7,142 $7,321 $7,504 $7,691 $7,884$8,081 $8,283 $8,490 $8,702 $8,920 $9,142Auxiliary power, capacity charge $9,834 $806 $658 $674 $691 $708 $726 $744 $763 $782 $802 $822 $842 $863 $885 $907 $930 $953 $977 $1,001 $1,026 $1,052Allowances ($61,788) ($5,064) ($4,611) ($4,885) ($3,626) ($3,858) ($4,091) ($4,337) ($4,556) ($4,802) ($5,035) ($5,295) ($5,569) ($5,856) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157) ($6,157)Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Total $673,725 $55,213 $62,623 $61,357 $61,632 $60,425 $59,227 $58,025 $60,579 $55,679 $54,522 $53,348 $52,171 $50,992 $49,810 $53,361 $48,085 $47,241 $46,410 $45,592 $44,787 $43,995Case 12: Wet FGD0.7% Sulfur Fuel, Unit 2Base NPPDMultiPol_Rev16-SOXNOX Levelized with Smaller Fan.xls, ProFormaPage 1 of 1Printed 2/7/2008, 12:53 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 wet limestone forced oxidation FGD System on Gerald Gentleman Station, Units

1&2.

Scope includes:

• Unit 1 Absorber Area

• Unit 2 Absorber Area

• Units 1&2 Common Areas (Reagent Prep and handling, solids dewatering and 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

• 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.

### Nebraska Public Power District

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

2/7/2008

Page 2 of 2 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.

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 4 

# Technical Basis

The following is a summary of the technical basis of the Phase 1 wet limestone forced

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

system capital cost estimate.

1. Limestone Handling common to both Units

a. Limestone rail car unloader

i. Bottom dump cars.

ii. Capable of unloading a 128 car unit train at 2000 TPH, once per

month. The station will be able to unload in 8 hrs if the train is not

split, 12-14 hrs if the train is split.

iii. Two steel (2) track hoppers including belt feeders.

iv. Track hopper building.

v. Fogging type dust suppression system.

vi. Heating and ventilation system.

vii. Vendor quote from Roberts and Schaefer Co.

b. Limestone stack out

i. Conveyor, 48 ft. wide, 450 ft. long, 2000 TPH, with enclosed gallery.

ii. Drop spout to grade (telescopic chute), no dust control.

iii. 30 day active pile and 30 day inactive pile.

iv. Bulldozer for moving limestone, about 4 hours/day.

v. Vendor quote from Roberts and Schaefer Co.

c. Limestone reclaim

i. Conveyor, 30 ft. wide, 525 ft. long, 500 TPH, with enclosed gallery.

ii. Two steel (2) reclaim hoppers including belt feeders.

iii. Heating and ventilation system.

iv. Vendor quote from Roberts and Schaefer Co.

2. Limestone Preparation common to both Units

a. Limestone day silo

i. 2 steel day silos with bin vent for dust control, 20 ft diameter, 60 ft

tall.

ii. Bin activator per silo.

iii. Silo level monitoring system.

iv. Vendor quote from Babcock Power and B&W.

b. Ball mills

i. Two (2) at 100% capacity, 1 operating 1 spare, each with a classifiers

to size the limestone, and a limestone slurry tank.

ii. Four (4) ball mill slurry pumps, 1 operating 1 spare per train.

iii. Two ball mill limestone weigh feeders.

iv. Two (2) limestone slurry feed pump s to recirculate slurry to each

absorber and back to the slurry tank.

v. Vendor quote from Babacok Power and B&W.

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

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

Page 2 of 4 c. Slurry Loop: Two (2), 1 operating and 1 sp are 950 lineal feet of pipe to Unit 1

absorber, Two (2), 1 operating and 1 spar e, 1500 lineal feet of pipe to Unit 2

absorber.

d. Limestone Prep Building.

3. Absorber Area per Unit

a. 1 68.5 ft. diameter absorber vessel per unit.

b. Vessel is alloy 2205.

c. Inlet wet/dry interface to FGD absorber is C-276.

d. L/G of 59.8 Unit 1 and 55.5 Unit 2 (gpm/kacfm).

e. Three (3) spray levels, 2 operating and 1 spare.

f. Two (2) trays pe r absorber, A2205.

g. Five (5) slurry recycle pu mps, 4 operating and1 spare.

h. Two (2) absorber bleed pump s, 1 operating and 1 spare.

i. Side entry agitators.

j. Two (2) levels of mist eliminators, FRP.

k. Two (2) mist eliminator water pumps, 1 operating and 1 spare.

l. Two (2) oxidation air compressors, 1 operating and 1 spare.

m. Absorber building.

n. Elevator in absorber area.

o. Hoists and trolleys.

p. Roofing.

q. Lighting, heating and ventilation.

r. Vendor quote from Babcock Power and B&W.

4. Emergency Quench System common to both Units

a. Diesel quench pump house.

b. Lighting HVAC.

c. Pump, piping and valves.

d. Emergency Diesel Generator.

5. Dewatering Area common to both Units

a. Two (2) primary hydroclones.

b. Two (2) vacuum belt filters, 1 operating and 1 spare.

c. One (1) make-up water tank with two (2) make-up water pumps, 1 operating

and 1 spare.

d. One (1) reclaim water tank with two (2) reclaim pumps, 1 operating and 1

spare.

e. Dewatering Building.

f. Vendor quote from Babcock Power and B&W.

6. Flues Including Support Steel per Unit

a. Fan outlet to absorber inlet

i. Carbon steel.

ii. Velocity = 4000 to 4500 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 4 b. Absorber to chimney

i. FRP.

ii. Velocity 4000 fpm.

c. Flue gas path reinforcement

i. No reinforcement.

7. New Chimney per Unit

a. New concrete shell with FRP liner.

b. 550’ height, 30 ft diameter.

c. Basic liquid collection system and drains in bottom.

d. Abandon existing chimney in place and it could be an optional bypass around

the FGD.

e. No capping of the old chimney included. The price is $1,900,000 per

chimney.

f. Vendor Quote from Hamon Custodis.

8. Control System Modifications per Unit

a. Based on number of I/O points. Each Unit has 1,218 I/O points.

9. Rail Yard Extension common to both Units

a. Use NPPD’s planned additional rail l oop to receive a unit train once per

month, already budgeted, do not include in estimate.

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

to be stored on site, already budge ted, do not include in estimate.

c. Add three ladder tracks to hold a unit train of 128 rail cars.

10. Subsurface and Foundation Work -All

a. Foundation system consists of drilled caissons.

11. Civil Work-All

a. Roads.

b. White rock surfacing.

12. 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 old chimney not in cluded. The approximate cost is $4,500,000

per chimney.

13. Pipe Racks common to both Units

a. Between reagent prep and absorber and dewatering areas

14. CEMS per Unit

a. New CEMS.

15. Water Treatment common to both Units

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

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

Page 4 of 4 a. Reaction tanks including 2 x 100% clarifiers and a sl udge dewatering system.

b. Preassembled and skid-mounted.

c. Water treatment building.

16. Instrument Air Compressor and Dryer common to both Units

17. Field Painting-All

a. Multiple coat system used for exposed ductwork only.

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

18. Performance Testing- All

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

19. Piping common to both Units

a. Water supply to oxidation air pi pe, reagent preparation and dewatering area

boundary from service water (50degF to 90 degF range).

b. Instrument air piping to ever y silo or day bin, bi n vent and reagent

preparation/dewatering area.

c. Heat traced piping.

20. Installation- All

21. New booster ID fans-All

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

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. One reagent prep electrical equipment building.

f. Two transformer elect rical equipment building.

g. Two main electrical equipment building.Nebraska Public Power DistrictGerald Gentleman Station Unit 1 & 2Estimate Summaryfor Wet 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. 22987B)Direct 59.685 17.420 62.964 490,103 140.069EPC portion 0.000 0.000 28.014 0 28.014Indirect 0.000 0.000 0.000 0 3.362Escalation 0.000 0.000 0.000 0 31.288Sales/Use Tax 0.000 0.000 0.000 0 4.241AFUDC 0.000 0.000 0.000 0 20.699Contingency @ 20%40.547268.220Unit 2 Absorber Area (Estimate No. 22997B)Direct 59.685 17.420 62.964 490,103 140.069EPC portion 0.000 0.000 28.014 0 28.014Indirect 0.000 0.000 0.000 0 3.362Escalation 0.000 0.000 0.000 0 33.446Sales/Use Tax 0.000 0.000 0.000 0 4.241AFUDC 0.000 0.000 0.000 0 24.354Contingency @ 20%40.978274.464Unit 1 & 2 Common Area (Estimate No. 22988B)Direct 56.063 28.657 78.026 695,864 162.746EPC portion 0.000 0.000 39.091 0 39.091Indirect 0.000 0.000 0.000 0 44.045Escalation 0.000 0.000 0.000 0 50.232Sales/Use Tax 0.000 0.000 0.000 0 4.660AFUDC 0.000 0.000 0.000 0 34.894Contingency @ 20%59.223394.891Unit 1 & 2 Auxil. Power & ID Fans (Estimate No. 22995B)Direct 20.792 6.337 22.641 261,376 49.770EPC portion 0.000 0.000 9.954 0 9.954Indirect 0.000 0.000 0.000 0 1.194Escalation 0.000 0.000 0.000 0 11.882Sales/Use Tax 0.000 0.000 0.000 0 1.492AFUDC 0.000 0.000 0.000 0 8.652Contingency @ 20%14.56097.504Project TotalsDirect 196.225 69.834 226.595 1,937,446 492.654EPC portion 0.000 0.000 105.073 0 105.073Indirect 0.000 0.000 0.000 0 51.963Escalation 0.000 0.000 0.000 0 126.848Sales/Use Tax 0.000 0.000 0.000 0 14.634AFUDC 0.000 0.000 0.000 0 88.599Contingency @ 20%155.308"All In" Grand Total with EPC Fee = 1035.079 690Grand Total without EPC Fee = 930.006 620Price 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 WET FGD SYSTEM GENERAL ARRANGEMENT

MS-WETFGD01

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.

10-04-2007 D.SKOIRCHET D.G.SLOAT

-------- A

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

-------- FILENAME:MSWETFGD0101.DGN

DESIGN FREEZE FOR COMMENTS 1"=100’ 2 1

6

7

0’ 100’ 100’ 200’ 300’ 400’ 8 9 10

3 3 4 5 11 12 13

14

15 16 17 18 19 20 21

MATCH LINE A-A MATCH LINE A-A



# 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

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 E

F

G H

J

K A B C

A B C



## PLAN PARTIAL PLAN

RAIL KEY:

EXISTING

PROPOSED NPPD ADDITIONS

NEW LIMESTONE UNLOADING L

NOTE:

ROADS IN AREA OF ABSORBER TOWER REWORKED. M P N

R S

S

22 22 T

T

NEW STRUCTURES KEY:

A. ABSORBER TOWER

B. SLURRY PUMP & OXIDATION AIR BLOWER BUILDING

C. CHIMNEY

D. LIMESTONE RAIL CAR UNLOADING

E. EMERGENCY COAL UNLOADING CONVEYOR

F. ACTIVE LIMESTONE PILE W/RECLAIM

G. INACTIVE LIMESTONE PILE

H. REAGENT PREPARATION BUILDING

J. WASTE DEWATERING BUILDING

K. GYPSUM STACK OUT

L. WASTE HAUL ROAD

M. GYPSUM EMERGENCY STACK OUT

N. WASTEWATER TREATMENT BUILDING

P. RECLAIM WATER TANK

R. WAREHOUSE

S. LIMESTONE RAIL CAR MARSHALLING YARD

T. ELECTRICAL BUILDING

U. FGD BOOSTER FANS

V. RESERVE SPACE FOR CO2 RECOVERY SYSTEM V V U U