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 Desulphurization

Capital and O&M Costs

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

Capital Costs

Absorber 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 $ 

Subtotal $ 168,083,000 168,083,000 $ 201,837,000 $ 59,724,000 $ 597,727,000 $ 

Other Costs

Indirect 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 $ 

Subtotal $ 106,381,000 100,137,000 $ 193,054,000 $ 37,780,000 $ 437,352,000 $ 

Total Capital Cost $ 274,464,000 268,220,000 $ 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 Costs

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

Analysis Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032Discount factor 0.9501 0.9027 0.8577 0.8149 0.7743 0.7356 0.6989 0.6641 0.6310 0.5995 0.5696 0.5412 0.5142 0.4885 0.4642 0.4410 0.4190 0.3981 0.3783 0.3594Capacity factor 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00%Energy production, GWh (with NPV) 56,866 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660 4,660Available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977SOX allowance surrender rate 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00Equivalent available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Equivalent SOX allowances used, tons (i.e., emissions) (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 13,761 13,761 13,761 13,761 13,761 13,761 13,761Tons SOX removed 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 41,338 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 removed 00000000000000000000Tons NOX removed 00000000000000000000Tons 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 masks

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

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

Fixed charge rates

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

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

Total

Fixed charges on investment, $1000s NPV RR Levelized

SOX $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 $26,794

Hg $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 $0

Total $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 $26,794

Extended outage purch power, $1000s

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $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 $0

Total $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Fixed O&M expense, $1000s

For 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 $5,426

Operating 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 $1,451

For Hg control:

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

For NOX control:

Maintenance (labor + mat'l) $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 $6,877

Variable O&M expense, $1000s

For 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 $3,502

Lime (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 $770SO3 reduction agent (Na2CO3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Solid waste sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid waste landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum landfill cost $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 $1,052

For Hg control:

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

For NOX control:

Urea $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 $0

For 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 $9,860

Fuel 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 $43,531

Summary Revenue Requirements NPV 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 $43,531

Case 11: Wet FGD0.7% Sulfur Fuel, Unit 1

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

Analysis Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20Calendar Year 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032Discount factor 0.9501 0.9027 0.8577 0.8149 0.7743 0.7356 0.6989 0.6641 0.6310 0.5995 0.5696 0.5412 0.5142 0.4885 0.4642 0.4410 0.4190 0.3981 0.3783 0.3594Capacity factor 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00% 80.00%Energy production, GWh (with NPV) 59,859 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906 4,906Available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977SOX allowance surrender rate 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00Equivalent available SOX allowances, tons 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977 14,977Equivalent SOX allowances used, tons (i.e., emissions) (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 13,682 13,682 13,682 13,682 13,682 13,682 13,682Tons SOX removed 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 41,866 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 removed 00000000000000000000Tons NOX removed 00000000000000000000Tons 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 masks

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

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

Fixed charge rates

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

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

Total

Fixed charges on investment, $1000s NPV RR Levelized

SOX $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 $27,123

Hg $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 $0

Total $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 $27,123

Extended outage purch power, $1000s

SOX $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Hg $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NOX $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 $0

Total $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Fixed O&M expense, $1000s

For 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 $5,426

Operating 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 $1,451

For Hg control:

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

For NOX control:

Maintenance (labor + mat'l) $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 $6,877

Variable O&M expense, $1000s

For 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 $3,552

Lime (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 $798SO3 reduction agent (Na2CO3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Solid waste sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Solid waste landfill cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum sales revenue $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Gypsum landfill cost $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 $1,229

Purchases (+) 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 $1,052

For Hg control:

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

For NOX control:

Urea $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 $0

For 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 $9,995

Fuel 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 $43,995

Summary Revenue Requirements NPV 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 $43,995

Case 12: Wet FGD0.7% Sulfur Fuel, Unit 2

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

General Gentleman Station, Units 1&2 

 Project No. 12194-001 

2/7/2008 

Page 1 of 2 

Basis of Estimate

Scope

This cost is based on installing a 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 the use of applicable construction crews typically 

required for projects of this type. 

4. Productivity

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

attract labor, weather conditions, etc. 

5. Quantity Sources

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

6. Project Schedule

To be determined. 
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 District 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 pumps to recirculate slurry to each 

absorber and back to the slurry tank. 

v. Vendor quote from Babacok Power and B&W. 
Nebraska Public Power District 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 spare 950 lineal feet of pipe to Unit 1 

absorber, Two (2), 1 operating and 1 spare, 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 per absorber, A2205. 

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

h. Two (2) absorber bleed pumps, 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 District 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 loop 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 budgeted, 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 included. 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 District 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 sludge 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 and 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 pipe, reagent preparation and dewatering area 

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

b. Instrument air piping to every silo or day bin, bin 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 existing 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 prep, dewatering, absorber and SCR. 

 e. One reagent prep electrical equipment building. 

 f. Two transformer electrical equipment building. 

 g. Two main electrical equipment building. 

 
Nebraska Public Power District

Gerald Gentleman Station Unit 1 & 2 Estimate Summary for Wet FGD 

Equipment Cost 

($ Millions)

Material Cost 

($ Millions)

Labor Cost 

($ Millions)

Erection Labor 

Man-Hours

Total 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% 40.547

268.220

Unit 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% 40.978

274.464

Unit 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% 59.223

394.891

Unit 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% 14.560

97.504

Project Totals

Direct 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 = 1035.079 690

Grand Total without EPC Fee = 930.006 620

Price Level = Q4, 2007

Page 1 of 1



















A

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

SHEET OF

DRAWING NO. REV.

SCALE

B

C

D

E

F

A

B

C

D

E

F

8 7 6 5 4 3 2 1

8 7 6 5 4 3 2 1

PROJECT

NUMBER

REV. DATE REL’D. PREPARED REVIEWED APPROVED PURPOSE

DRAWING RELEASE RECORD

 POWER DISTRICT 

 NEBRASKA PUBLIC 

 GERALD GENTLEMAN STATION 

 EQUIPMENT PROJECT 

 MULTI-POLLUTANT CONTROL 

 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.

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

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

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FILENAME:MSWETFGD0101.DGN 

 

 

DESIGN FREEZE 

FOR COMMENTS 

1"=100’ 

1 2

6

7

100’ 0’ 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

E D

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