**An droscoggin Power Boilers #1 or #2** 

**Given/A ssumptions**  New or Retrofit? Retrofit Extra retrofit cost factor 1.0 Generation capacity

(MW ) 68 SCR by pass included? No Fuel High Heating Value (Btu/gal) 150,000 Maximum Fuel Consumption Rate (gal/hr) 4.5E+03 Maximum Annual Fuel Consumption (gal) 3.97E+07 Maximum Annual Heat Input (mmBtu) 5.96E+06 Number of SCR Operating Days 365 Uncontrolled NOx Concentration (lb/mmBtu) 0.41 Uncontrolled NOx Emissions (tpy ) 383 Actual annual heat input (mmBtu) 1.87E+06 Required Controlled NOx Concentration (lb/mmBtu) 0.041 Acceptable Ammonia Slip (ppm) 2.0 Fuel Volum e Flow Rate (dscf/mmBtu) 9,190 Fuel Sulfur Content 0.70% Number of SCR reactor chambers 1 ASR 1.05 Stored Ammonia Concentration 29% Reagent Molecular W eight (g/mole) 17.03 Reagent Density

(lb/ft3 @ 60F) 56.0 Reagent Specific Volume (gal/ft3) 7.481 NOx Molecular W eight (g/mole) 46.01 Number of Days of Storage for Ammonia 14 Pressure Drop for SCR Ductwork H2O") 3 Pressure Drop for each Catalyst Layer (H2O") 1 Temperature at SCR Inlet (degrees F) 650 Equipm ent Life (years) 20 Annual Interest Rate 7% Inflation Since 1998 1.35 Catalyst Cost, Initial ($/ft3) 85 $ Catalyst Cost, Replacement ($/ft3) 85 $ Electrical Power Cost ($/kW h) 0.08 29% Ammonia Solution Cost ($/lb) 0.058 Operating Life of Catalyst (hours) 24,000OAQPS Control Cost Manual

estimated estimated OAQPS Control Cost Manual company

report calculated 680 mmB tu/hr from company report calculated calculated assumed company

report company

report calculated calculated from company estimate OAQPS Control Cost Manual AP-42 6,249,200 company

report OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual OAQPS Control Cost Manual CEPCI 2007/CEPCI 1998 calculated 3,000 $ /m3 from PacifiCorp report calculated 3,000 $ /m3 from PacifiCorp report company

report calculated 400.00 $ /ton from PacifiCorp report OAQPS Control Cost Manual**Boiler Calculations**



### 2.3 Q B 

### = HVm-dot fuel QB = 150,000 Btu/gal * 4,533 gal/hr QB = 680 mmB tu/hr



### 2.7 CF Plant 

### = actual m fuel

### /maximum m fuel CFPlant = 1.87E+06 mmB tu/y r / 5.96E+06 mmB tu/y r CFPlant = 31%



### 2.8 CF SCR 

### = t SCR



### /365 day s CFSCR = 365 days/ 365 days CFSCR = 100%



### CF Total 

### = CF Plant 

### x CF SCR CFTotal = 31% * 100% CFTotal = 31%



### 2.12 q fluegas 

### = q fuel 

### Q B 

### (460+T)/(460+700 o 

### F)n SCR qfluegas = 9,190 ft3/min/(mmBtu/hr)* 680 mmB tu/hr*( 460 + qfluegas = 5,979,838 acfm



### 2.9 η NOx

### = (NOx in

### – NOx out 

### ) / NOx in ηNOx = ( 0.41 lb/m mB tu - 0.041 lb/m mB tu)/ 0.41 ηNOx = 90%
**Uncontrolled NOx emissions (tpy) 383** 650 )/( 460 + 700 )/ 1

lb/m mB tu**SCR Reactor Calculations**



### 2.19 Volcatalyst



### = 2.81 x Q B 

### x η adj 

### x Slip adj 

### x NOx adj 

### x S adj 

### x T adj 

### /N SCR Volcatalyst = 2.81 * 680 = 1911



### 2.2 η adj 

### = 0.2869 + (1.058 x η) ηadj = 0.2869 +( 1.058 * 0.90 ) ηadj = 1.239 

### 2.22 Slip adj 

### = 1.2835 – (0.0567 x Slip) Slipadj = 1.2835 - ( 0.057 * 2 ) Slipadj = 1.170 

### 2.21 NOx adj 

### = 0.8524 + (0.3208 x NOx in

### ) NOxadj = 0.8524 + ( 0.321 * **0.41** ) NOxadj = 0.984 

### 2.23 S adj 

### = 0.9636 + (0.0455 x S) Sadj = 0.9636 + ( 0.046 * 0.7 ) Sadj = 0.995 

### 2.24 T adj 

### = 15.16 – (0.03937 x T) + (2.74 x 10 -5 

### x T 2 

### ) Tadj = 15.16 - ( 0.039 * 650 ) + 2.74E-05 * Tadj = 1.146 Volcatalyst = 3,110 ft3 each = 88.12 m3 each



### 2.25 Acatalyst



### = q fluegas

### /(16 ft/sec x 60 sec/min) Acatalyst = 5,979,838 /( 16 * 60 ) Acatalyst = 6229 ft2



### 2.26 A SCR



### = 1.15 x Acatalyst ASCR = 1.15 * 6229 ASCR = 7163 ft2



### 2.27 l = w = A SCR 1/2
l = w = 84.6 ft



### 2.28 nlayer 

### = Volcatalyst



### /(h’ layer 

### x Acatalyst

### ) nlayer = 3110 /( 3.1 * 6229 ) nlayer (calc) = 0.2 nlayer = 2.0



### 2.29 hlayer 

### = [Volcatalyst



### /(nlayer 

### x Acatalyst

### )] + 1 hlayer = 3110 /( 2.0 * 6229 ) + 1 hlayer = 1.2



### 2.3 n total

### = nlayer



### + nempty ntotal = 2 + 1 ntotal = 3

### 2.31 h SCR 

### = n total 

### (c 1 

### + hlaye

### r) + c 2 hSCR = 3 * ( 7 + 1.2 ) + 9 hSCR = 34 ft422500**Reagent Calculations**



### 2.32 m- dot reagent



### = NOx in 

### Q B 

### ASRη NOx

### M reagent 

### /MNOx m-dotreagent = **0.41** * 680 * 1.05 * **90%** * 17.03 m-dotreagent = 98 lb/hr



### 2.33 m- dot sol

### = m-dot reagent 

### /C sol m-dotsol = 98 / 0.29 m-dotsol = 336 lb/hr



### 2.34 q sol

### = (m-dot vol

### /ρ sol 

### )V sol qsol = 336 * 7.481 / 56 qsol = 45 gph



### 2.35 Tank Volume = q sol 

### t Tank Volume = 45 * 14 * 24 Tank Volume = 15,094 gal/ 46.01**Direct Capital Cost**



### 2.36 DC = Q B 

### [($3380/MMBtu/hr) + f(h SCR

### ) +f(NH 3 

### rate) + f(new) + f(bypass)](3500/Q DC = 680 (( 3,380 $ + 

### 2.37 f(h SCR

### ) = {[$612/(ft-m mBt u/hr)]h SCR 

### } - $187.9/(m mBt u/hr) f(hSCR) = 6.12 * 34

- 187.9 

### f(hSCR) = 19

$ /mmBtu/hr



### 2.38 f(NH 3 

### rate) = [($411/l b/hr)(m-dot reagent



### /Q B 

### )] - $47.3/(m

mBt u/hr) f(NH3rate) = 411 * 98 / 680

- 47.3 

### f(NH3rate) = 12

$ /mmBtu/hr 

### 2.39 f(new) = $0/(mmBtu/hr) for retrofit f(new) =

-

$ 2.41 f(bypass) = $0/(mmBtu/hr) for no bypass f(bypass) =

-

$ /mmBtu/hr 

### 2.43 f(Volcatalyst

### ) = Volcatalyst 

### CCinit ial f(Volcatalyst) = 3110 * 85 f(Volcatalyst) = 264,370

$

DC = 680 * ( 3,380 $ + 19

$ + 12

$ + DC = 4,379,136 $ for each reactor DC = 4,379,136 $ for all reactors **Inflation Adjustment =** 1.35

DC = 5,911,834 $

### rate) + f(new) + f(bypass)](3500/Q B 

### ) 0.35 

### + f(Volcatalyst

### )
} - $187.9/(m

mBt u/hr)

)] - $47.3/(m

mBt u/hr)

- $ +

-

$ )*( 3500 / 680 )^ 0.35 + 264,370 $**Indirect Capital Costs**

**Total Direct Capital Costs, A** Indirect Installation Costs

General Facilities 0.05 A Engineering and Hom e Office Fees 0.10 A Process Contingencies 0.05 A **Total Indirect Installation Costs, B** Retrofit factor = 1.0 * 0.20 A =

Project Contingency , C = Retrofit factor = 1.0 * 0.15 (A+B) = **Total Plant Cost D =**

Allowance for Funds During Construction, E = 0 Royalty Allowance, F = 0 Preproduction Cost, G = 0.02 Inventory Capital, H = Initial Catalyst and Chemicals, I = 0.058 /lb * 336 lb/r * 24 hr/day * **Total Capital Investment TCI = D+G+H**5,911,833.67
$295,592 $591,183 $295,592 0.20 A = $1,182,367 0.15 (A+B) = $1,064,130 A+B+C $8,158,330 $0 $0 (D+E) $163,167

14 days = $6,553 +D+E+F+G+H+I $8,328,050 Cost/kW = $122**Annual Costs**



### 2.45 DAC = Annual Maintenance Cost + Annual Reagent Cost + Annual Electricity Cost + Annual Water Cost + Annual Catalyst Cost 2.46 Annual Maintenance Cost = 0.015 TCI Annual Maintenance Cost = 0.015 * **8,328,050 $**  Annual Maintenance Cost = 124,921 $ 

### 2.47 Annual Reagent Cost = qreagent 

### Cost reagent

### t op 

### 2.47a t op

### = CF total 

### 8760hr/yr top = 31% * 8760 

### top = 2748 Annual Reagent Cost = 336 * 2748 * 0.058 Annual Reagent Cost = 53,600 $ 

### 2.49 Annual Electricity Cost = Power (Cost elect) 

### t op 

### 2.48 Power = 0.105Q B 

### [NOx in 

### ηNOx + 0.5(ΔP duct



### + n total 

### ΔP catalyst Power = 0.105 * 680 *( **0.41** * Power = 241 kW Annual Electricity Cost = 241 * 2748 * 0.08 Annual Electricity Cost = 52,886 $ 

### 2.51 Annual Catalyst Replacement Cost = (Catalyst Replacement Cost)FWF 2.5 Catalyst Replacement Cost = n SCR

### Volcatalyst 

### CC replace

### /Rlayer Catalyst Replacement Cost = 1 * 3110 * 85.01581521 / Catalyst Replacement Cost = 132,185 $ 

### 2.52 FWF = i{1/[(1+i) Y 

### -1]} 2.53 Y = hcatalyst



### /h year Y = 24000 /( 100% * 8760 ) Y = 3 FW F = 0.07 *( 1 /( 1 + FW F = 0.31 Annual Catalyst Cost = 41,116 $ 

### DAC = **272,523 $** 



### 2.55 CRF = i(1+i) n



### /[(1+i) n 

### -1] CRF = 0.07 *( 1 + 0.07 )^ CRF = 0.0944

Indirect Annual Cost = CFR * TCI Indirect Annual Cost = 0.0944 * **8,328,050 $**  Indirect Annual Cost = 786,109 $



### 2.56 Total

Annual Cost = Direct Annual Cost + Indirect Annual Cost Total Annual Cost = 272,523

$ + 786,109 Total Annual Cost = **1,058,632**

**$**



### 2.57 NOx Removed = NOxin 

### η NOx 

### Q B 

### t op NOx Removed = **0.41** * 90% * 680 * NOx Removed = 345

### 2.58 Cost effectiveness = TAC/NOx removed SCR Cost effectiveness ($/ton) = 3,070 $

Greatest dv improvement = 0.85 SCR Cost effectiveness ($/dv) = 1,245,449 $ Cumulative dv improvement = 2.3 SCR Cost effectiveness ($/dv) = 460,275 $

### DAC = Annual Maintenance Cost + Annual Reagent Cost + Annual Electricity Cost + Annual Water Cost + Annual Catalyst Cost

catalyst

### )] 90% + 0.5 * ( 3 + 3 * 1 ))



### Annual Catalyst Replacement Cost = (Catalyst Replacement Cost)FWF

2

0.07 )^ 3

- 1 )

20 /(( 1 + 0.07 )^ 20

- 1 )



### Total Annual Cost = Direct Annual Cost + Indirect Annual Cost

2748 / 2000Mill High (dv) Class I Area Mill PB #1+#2 Acadia NP 3.7 2.8 Great Gulf W A 2.2 1.7 Lye Brook W A 1.0 Moosehorn W A 1.7 1.3 Presidential Range-Dry River W A 2.9 2.3 Roosevelt Campobello IP 1.6 13.1 8.1

PB #1+#2 High (dv) Class I Area 0.7% S WS SCR SNCR Acadia NP 1.9 1.3 1.1 1.4 Great Gulf W A 1.0 0.8 0.7 Lye Brook W A Moosehorn W A 0.7 0.3 0.6 0.6 Presidential Range-Dry River W A 1.3 0.8 1.0 1.1 Roosevelt Campobello IP 4.9 2.4 3.5 3.8Improvement (dv)

0.7% S WS SCR SNCR 0.9 1.5 1.7 1.4 0.7 0.9 1.0

0.6 1.0 0.7 0.7 1.0 1.5 1.3 1.2

3.2 4.0 4.6 4.3