**Capital Costs Total Direct Capital** 

Technology LNB-OFA **Material Capital Costs 1**  **Total Capital Cost Plus Installation** $16,000,000

**Annual Costs 2**  Parameters/Costs Equation Unit 1 Boiler design capacity, mmBtu/hr (C) C 6324 Annual operating hours, hr/yr (H) H = average from 2001-2003 7752
Capital recovery factor = [ I x (1+i)^a]/[(1+i)^a - 1], where I = interest rate, a = equipment life 0.11 a. Equipment CRF, 15-yr life, 7% interest
Direct Annual Operating Costs $/yr

Variable O&M Costs =(0.027 mills/kW-hr/1000) x (1 kW-hr/10,000 Btu) x H x C x 10^6 Btu/mmBtu $132,364
Indirect Annual Costs, $/yr 1. Fixed O&M Costs (1.5% of capital cost) = 0.015 x TCI $240,000 2. Annualized capital cost = Equipment CRF x TCI $1,756,714 **Total Annual Costs ($/yr)** $2,129,078 **LNB/OFA Capital and O&M Cost Estim ate** 

1 Public Service Commission Docket 12-008-U.

2Annual cost calculation methods for variable costs and fixed costs from Eastern Research Group "Analysis of Combustion Controls for Reducing NOx Emissions from Coal-fired EGUs in the WRAP Region" September 6, 2005. Section 4.3.1 and Appendix D. Note: The variable rate used for variable O&M costs was 0.027 mills/kW-hr. This is the rate listed in Appendix D**Capital Costs Total Direct Capital** 

Technology SCR
Installed Capital Cost 1 $121,440,000

**Annual Costs**

Variable Urea 1 $2,200,000 Catalyst replacement (per year) 1 $1,500,000 Total Variable O&M 1 $3,700,000

Fixed Operating Labor Cost2 $530,000 Maintenance Labor 3 $530,000 Maintenance Material 1 $500,000 Total Fixed O&M 1 $1,560,000 = [ I x (1+i)^a]/[(1+i)^a - 1], w here I = interest rate, a = equipment life 0.09 a. Equipment CRF, 20-yr life, 7% interest Annualized capital cost = Equipment CRF x TCI $11,463,077 **Total Annual Costs ($/yr)** $16,723,077

2Annual estimates provided by AEP based on 1 person per shift for 5 shifts.
3 Annual estimates provided by AEP based on 1 person per shift for 5 shifts. Capital recovery factor **SCR Capital and O&M Cost Estim ate** 

1 All capital and O&M cost estimates provided by AEP are based on engineering estimates. The engineering estimates were informed by AEP's experience with SCR installations at other plants owned by AEP**Capital Costs**
Technology SNCR Parameters/Costs Equation Unit 1 Boiler design capacity, mmBtu/hr (Q B ) Q B 6324 Total operating time (top , hrs/y r) top= CF total× 8760 hrs/y r 7752 Total Capacity

Factor (CF total ) CF total= CF plant × CF SNCR 0.92 Plant Capacity

Factor (CF plant) 2 0.92 SNCR Capacity

Factor (CF SCNR) 3 CF SNCR = t SNCR/365 1 Assumed NOx removal efficiency (η NOx) 4 35% Uncontrolled NOx rate (NOxin, lb/MMBtu) 5 0.33 Electricity

Cost (Costelect , $/kwh) 6 $0.05 Water Cost (Costwater , $/gal) 7 $0.00362 Coal Cost (Costcoal , $/MMBtu) 8 $2.50 Coal HHV (Btu/lb) 9 9,000 Cost of Ash Disposal (C ash , $/ton) 10 $9.0 Capital recovery

factor (CRF) CRF = [ I x (1+i)^a]/[(1+i)^a - 1], where I = interest rate, a = equipment life 0.09 a. Equipment CRF, 20-y r life, 7% interest Cost Index 10 a. 2011 Cost Index 585 b. 1998 Cost Index 389.5 **Capital Costs** Direct Capital Cost (A) DC ($) = ($950/MMBtu) × Q B × ((2375 MMBtu/hr/Q B )^0.577) × (0.66 + 0.85 η NOx) × (CI2011 /CI 1998 ) $5,007,199 Indirect Installation Costs ($) General Facilities 0.05 × A $250,360 Engineering and Home Office Fees 0.10 × A $500,720 Process Contingency 0.05 × A $250,360 Total Indirect Installation Costs (B) = General Facilities Cost + Engineering and Home Office Fees + Process Contingency $1,001,440 Other Installation Costs ($) Project Contingency

(C) C = 0.15 × (A + B) $901,296 Total Plant Cost (D) D = A + B + C $6,909,934 Allowance for Funds During Construction (E) E = 0 (Assumed for SNCR) $0 Roy alty Allowance (F) F = 0 (Assumed for SNCR) $0 Preproduction Cost (G) G = 0.02 × (D + E) $138,199 Inventory Capital (H) 11 H = Volreagent(gal) × Costreagent($/gal) $76,102 Costreag , 50% Urea solution ($/gal) 12 1.54 Volume of Reagent Tank (Vol reagent(gal)) Volreagent(gal) = q solx days of reagent supply × 24 hr/day 49,417 Urea solution volumetric flow rate (q sol , gal/hr) 13 q sol= (m solx 7.481 gal/ft3 )/ρ reagent 147.07 Mass flow rate of urea solution (m sol , lb/hr) 14 m sol= mreagent/C ureasol 1,395.84 Mass flow rate of reagent (mreagent , lb/hr) 15 mreagent= (NOxin x Q B x η NOx

× NSR x M reagent)/(MNOx

x SRT ) 697.92 Normalized Stoichiometric Ratio (NSR) NSR = ([2 × NOxin + 0.7] × η NOx)/NOxin 1.43 Initial Cataly

st and Chemicals (I) I = 0 (Assumed for SNCR due to no catalyst) $0 **Total Capital Investment (TCI) (Capital Cost) TCI = D + E + F + G + H + I**  **$7,124,235**
**Annual Costs ($)** Annual Maintenance Cost (J) J = 0.015 × TCI $106,864 Annual Reagent Cost (K) K = q sol× Costreag× top $1,755,781 Annual Electricity

Cost (L) L = P × Costelect× top $58,064 Power (P, kW) P = (0.47 × NOxin × NSR × Q B )/9.5 149.80 Annual Water Cost (M) M = qwater × Costwater

× top $18,775 Water flowrate for SNCR system (qwater , gal/hr) 16 qwater = (m sol/ρ water) × [(C ureasolstored/C ureasolinj ) - 1] 669.06 Annual ΔCoal Cost (N) N = ΔCoal × Costcoal× top $109,558 Additional coal required (ΔCoal, MMBtu/hr) 17 ΔCoal = (Hv × mreagent× [(1/C ureasolinj ) - 1])/10 6Btu/MMBtu 5.65 Annual ΔAsh Cost (O) O = (ΔAsh × Costash × top)/2000 lb/ton $1,643 Additional ash generated (ΔAsh , lb/hr) 18 ΔAsh = (ΔCoal × ashproduct × 10 6Btu/MMBtu)/HHV 47.11 **Direct Annual Costs (DAC)/Variable O&M DAC = J + K + L + M + N + O**  **$2,050,684**
**Indirect Annual Costs (IDAC)/Annualized Capital Cost IDAC = CFR × TCI**  **$672,477 Total Annualized Costs (TAC)**  **TAC = DAC + IDAC $2,723,162**  **Selective Non-Catalytic Reduction Capital and O&M Cost Estimate 1** 1 All SNCR costing equations from EPA Air Pollution Control Cost Manual (APCCM), 6th Edition (January 2002)
2 Plant capacity

factor from plant data
3 t SCNRassumed to be 365 days 4η NOx (NOx removal efficiency ) assumed to be 33% for SNCR alone
5 24-hr NOx rate 46,680 lbs/day - from Clean Air Markets Database, with a heat input of 6324 MMBtu/hr
6Electricity

cost form Arkansas Industrial Energy Clearinghouse, http://www.arkansasiec.org/newsmanager/templates/?a=71&z=1
7 Water cost estimate from Bentonville, AR commercial rate of $0.00362/gal, http://www.bentonvillear.com/utbc_rates.html
8 Cost of coal from Lazard's 2009 Levelized Cost of Energy Analysis (LCOE)

10Cost of ash disposal from BART Analy sis for NCS Unit 1, Appendix A
11 From Chemical Engineering Plant Cost Index (CEPCI)
12 Cost for urea stored on site, i.e., the first fill of the reagent tanks.

14ρ reagent= 71.0 lb/ft3

15 C ureasol= urea solution concentration = 50%

18 Approximate heat of vaporization of water at 310°F, Hv = 900 Btu/lb From EP A APCCM, 2002

19 Ashproduct is the fraction of ash produced as a by product of burning a given ty pe of coal. Assumed ashproduct = 0.075 from EPA APCCM, 2002 for subbituminous coal. 9 Coal used at AEP Flint Creek originates from Powder River Basin near Gillette, WY and is considered to be subbituminous (source: http://www.aecc.com/about/generationfacilities/) HHV for subbituminous coal ranges from 8,000 - 10,000 Btu/lb (EPA APCCM, 2002). Using HHV of 9,000 Btu/lb

13 Five-y r average urea cost = $356.11/metric ton, from http://www.indexmundi.com/commodities/?commodity =urea&months=180 Density of 50% urea solution = 9.5 lb/gal (50% urea solution) based on EPA APCCM, 2002 Equates to $1.54/gal

16 M reagent= 60.6 g/mol (molecular weight of urea) MNOx = 46.01 g/mol (molecular weight of NO 2 ) SRT = 2 (ratio of equivalent moles NH 3 per mole of urea)

17 Concentration of stored urea, C ureasolstored= 50% Concentration of urea injected into SNCR sy stem, C ureasolinj = 10% From EPA APCCM, 2002**Capital Costs 1** 

NID FGD + FF 243,881,264 $ NID By-Product Handling 38,792,582 $ Balance of Plant (BOP) Construction Total 59,656,085 $ Contingency & Allocations 88,119,783 $ Total Capital Investment (TCI) 430,449,714 $

**Annual Costs** Variable O&M 2 $/year $6,620,000

Auxiliary Power2 $/year $4,186,080 Total Fixed O&M 2 $/year $4,210,000

= [ I x (1+i)^a]/[(1+i)^a - 1], w here I = interest rate, a = equipment life 0.08 a. Equipment CRF, 30-yr life, 7% interest Annualized Capital Cost = Equipment CRF x TCI $34,688,394 **Total Annual Costs ($/yr)** $49,704,474

2 Total O&M Costs ($/year) from AEP based on information gathered from a detailed estimate developed for the simailar study at another AEP facility (Big Sandy FGD Project), scaled to account for the slightly smaller unit size at Flint Creek. **NIDS Capital and O&M Cost Estim ate** 

Capital recovery factor

1 From "FC DFGD & FF Budgetary Cost Estimate Breakdown (Class 4)."**Capital Costs 1** 

WFGD + FF 444,439,524 $ Waste Water Treatment 22,685,874 $ Boiler Modifications 3,816,274 $ Balance of Plant (BOP) Construction Total 15,708,422 $ Contingency & Allocations 46,599,533 $ Total Capital Investment (TCI) 533,249,627 $

**Annual Costs** Variable O&M 2 $/year $5,360,000

Auxiliary Power2 $/year $8,023,320 Total Fixed O&M 2 $/year $4,730,000

= [ I x (1+i)^a]/[(1+i)^a - 1], w here I = interest rate, a = equipment life 0.08 a. Equipment CRF, 30-yr life, 7% interest Annualized Capital Cost = Equipment CRF x TCI $42,972,670 **Total Annual Costs ($/yr)** $61,085,990

2 Total O&M Costs ($/year) from AEP based on information gathering from a detailed estimate developed for the simailar study at another AEP facility (Big Sandy FGD Project), scaled to account for the slightly smaller unit size at Flink Creek.

**Wet Flue Gas Desulfurization (WFGD) Capital and O&M Cost Estim ate** 

Capital recovery factor

1 From "Budgetary Cost Estimate Breakdown for FC WFGD & FF."**AEP Flint Creek**

**Baseline Em issions** 

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **No. of**

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **No. of**

**Days with ∆dv ≥ 0.5**  Caney Creek 21 3 0.668 14 4 0.734 20 Hercules-Glades 24 5 0.730 19 3 0.734 17 Mingo 13 3 0.653 7 0 0.444 4 Upper Buffalo 27 9 1.034 21 10 1.066 28 **2001 2002** **Total Total**  **Highest**

**No. of Days with**  **∆dv ≥ 1.0 98th** 

**Percentile ∆dv**  **No. of Days**

**with ∆dv ≥**  **0.5 No. of Days** 

**with ∆dv ≥**  **1.0 98th** 

**Percentile ∆dv**  **Max Impact**  **∆dv** 7 0.993 55 14 0.993 1.408 4 0.705 60 12 0.734 2.186 2 0.409 24 5 0.653 1.553 4 0.745 76 23 1.066 2.585 **2003 AEP Flint Creek** 

**Post Control Em issions** 
**Scenario 1 - NOx Control (SCR)**

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  Caney Creek 7 1 0.499 1.105 9 0 0.583 Hercules-Glades 18 3 0.627 1.405 11 1 0.601 Mingo 10 0 0.611 0.913 2 0 0.404 Upper Buffalo 20 4 0.701 1.758 16 8 1.011
**Scenario 2 - SO2 Control (Dry Scrubber)**

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  Caney Creek 1 0 0.346 0.587 3 0 0.309 Hercules-Glades 1 0 0.263 0.656 2 0 0.311 Mingo 3 0 0.216 0.693 0 0 0.189 Upper Buffalo 7 1 0.497 1.121 4 2 0.316
**Scenario 3 - NOx Control (LNB + OFA)**

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  Caney Creek 17 2 0.614 1.286 10 3 0.706 Hercules-Glades 22 5 0.652 1.422 14 3 0.683 Mingo 11 2 0.639 1.224 6 0 0.433 Upper Buffalo 24 5 0.926 1.786 18 8 1.030
**Scenario 4 - NOx Control (LNB + OFA + SNCR)**

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  Caney Creek 16 2 0.594 1.255 10 2 0.679 Hercules-Glades 22 5 0.646 1.419 13 2 0.676 Mingo 11 2 0.634 1.170 5 0 0.431 Upper Buffalo 23 4 0.887 1.781 18 8 1.028 Note: Since this is refined modeling (using the refined CALMET dataset), use the 98th percentile or 8th highest value in analyzing visibility. (Source: Letter from Guy Donaldson at EPA to Anthony Davis at ADEQ, dated 4/26/12)

**Scenario 5 - SO 2**  **Control (Wet Scrubber)**

**Class I Area No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  Caney Creek 1 0 0.353 0.616 3 0 0.342 Hercules-Glades 1 0 0.283 0.722 2 0 0.348 **2001 2002** 

**2001 2002** 

**2001 2002**  **2001 2002** 

**2001 2002** Mingo 3 0 0.225 0.720 0 0 0.201

Upper Buffalo 8 2 0.523 1.236 4 2 0.340**Total Total**  **Highest Highest** 

**Max Im pact**  **∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max**

**Impact ∆dv** 
0.991 17 3 0.784 1.043 33 4 0.784 1.105 1.017 14 3 0.614 1.676 43 7 0.627 1.676 0.836 4 1 0.311 1.167 16 1 0.611 1.167 1.816 19 3 0.621 1.297 55 15 1.011 1.816

**Total Total**  **Highest Highest** 

**Max Im pact**  **∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max**

**Impact ∆dv**  0.749 2 0 0.335 0.673 6 0 0.346 0.749 0.730 2 0 0.269 0.878 5 0 0.311 0.878 0.388 1 0 0.201 0.630 4 0 0.216 0.693 1.469 1 0 0.308 0.512 12 3 0.497 1.469

**Total Total**  **Highest Highest** 

**Max Im pact**  **∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max**

**Impact ∆dv**  1.164 19 5 0.924 1.265 46 10 0.924 1.286 1.285 15 4 0.676 2.023 51 12 0.683 2.023 0.867 4 2 0.375 1.427 21 4 0.639 1.427 2.294 26 4 0.719 1.352 68 17 1.030 2.294

**Total Total**  **Highest Highest** 

**Max Im pact**  **∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max**

**Impact ∆dv**  1.134 19 5 0.900 1.213 45 9 0.900 1.255 1.229 15 4 0.665 1.964 50 11 0.676 1.964 0.862 4 2 0.363 1.382 20 4 0.634 1.382 2.188 26 4 0.712 1.342 67 16 1.028 2.188
Since this is refined modeling (using the refined CALMET dataset), use the 98th percentile or 8th highest value in analyzing visibility.

**Total Total**  **Highest Highest** 

**Max Im pact**  **∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max Im pact** 

**∆dv No. of** 

**Days with ∆dv ≥ 0.5**  **No. of**

**Days with ∆dv ≥ 1.0**  **98th**

**Percentile ∆dv**  **Max**

**Impact ∆dv**  0.808 2 0 0.337 0.716 6 0 0.353 0.808 0.749 2 0 0.276 0.885 5 0 0.348 0.885 **2003**

**2003**

**2003 2003** 

**2003**0.403 1 0 0.210 0.637 4 0 0.225 0.720

1.523 1 0 0.370 0.509 13 4 0.523 1.523max impact 98% #days %vis improvement

1.105 0.784 33 21.0% 1.676 0.627 43 14.6% 1.167 0.611 16 6.4% 1.816 1.011 55 5.2%

0.749 0.346 6 65.2% 0.878 0.311 5 57.6% 0.693 0.216 4 66.9% 1.469 0.497 12 53.4%

1.286 0.924 46 6.9% 2.023 0.683 51 6.9% 1.427 0.639 21 2.1% 2.294 1.030 68 3.4%

1.255 0.900 45 9.4% 1.964 0.676 50 7.9% 1.382 0.634 20 2.9% 2.188 1.028 67 3.6%Baseline Emission Rate Controlled

Emission Level 1 Annual Heat

Input 3 Controlled

Emission Rate SO 2Reduced Capital Cost (tpy) (lb/MMBtu) (MMBtu/yr) (tpy) (ton/yr) ($) NIDS 2 11,641.00 0.06 37,344,776 1,120.34 10,520.66 430,449,714 Wet Scrubber2 11,641.00 0.04 37,344,776 746.90 10,894.10 533,249,627

2NIDS and Wet Scrubber cost information from vendor communciation/estimates 1 EPA Basic Concepts in Environmental Sciences, Module 6: Air Pollutants and Control Techniques http://www.epa.gov/eogapti1/module6/sulfur/control/control.htm In conjunction with vendor estimates

3 Baseline heat input was determined from CAMD, 2001-2003, average daily heat inputs times the average number of operating hours from 2001-2003.Annual

Capital Cost Annual Fixed

O&M Annual

Variable O&M Total Annual

Cost Cost

Effectiveness Incremental

Cost ($/yr) ($/yr) ($/yr) ($/yr) ($/ton) ($/ton) 34,688,394 4,210,000 10,806,080 49,704,474 4,724

- 42,972,670 4,730,000 13,383,320 61,085,990 5,607 30,477

Baseline heat input was determined from CAMD, 2001-2003, average daily heat inputs times the average number of operating hours from 2001-2003.**Baseline Em ission**  **Rate Controlled** 

**Emission Level**  **Annual Heat**

**Input 4**  **Controlled**

**Emission Rate**  **NOx**

**Reduced Capital Cost**  (tpy) (lb/MMBtu) (MMBtu/yr) (tpy) (ton/yr) ($) LNB/OFA 1 5,120.27 0.23 37,344,776 4294.65 825.62 16,000,000 LNB/OFA/SNCR2 5,120.27 0.20 37,344,776 3771.82 1348.44 23,124,235 SCR3 5,120.27 0.07 37,344,776 1251.05 3869.22 121,440,000

3 SCR Cost information: Please refer to Appendix B. 1 LNB Cost information: Please refer to Appendix B. 2SNCR Cost information: Please refer to Appendix B.

4Baseline heat input was determined from CAMD, 2001-2003, average daily heat inputs times the average number of operating hours from 2001-2003 divided by 24 hours in a day.**Annual**

**Capital Cost Annual** 

**Fixed O&M Annualized** 

**Variable O&M**  **Total**

**Annual Cost**  **Cost**

**Effectiveness Increm**  **ental**

**Cost** ($/yr) ($/yr) ($/yr) ($/yr) ($/ton) ($/ton) 1,756,714 240,000 132,364 2,129,078 2,579

- 2,429,191 240,000 2,183,048 4,852,239 3,598 5,209 11,463,077 1,560,000 3,700,000 16,723,077 4,322 4,795

Baseline heat input was determined from CAMD, 2001-2003, average daily heat inputs times the average number of operating hours from 2001-2003 divided by 24 hours in a day.SO2 - NIDS

Caney Creek 0.993 0.346 0.647 Hercules-Glades 0.734 0.311 0.423 Mingo 0.653 0.216 0.437 Upper Buffalo 1.066 0.497 0.569

SO2 - WFGD

Caney Creek 0.993 0.353 0.640 Hercules-Glades 0.734 0.348 0.386 Mingo 0.653 0.225 0.428 Upper Buffalo 1.066 0.523 0.543

NOx - LNB/OFA

Caney Creek 0.993 0.924 0.069 Hercules-Glades 0.734 0.683 0.051 Mingo 0.653 0.639 0.014 Upper Buffalo 1.066 1.03 0.036

NOx - LNB/OFA/SNCR

Caney Creek 0.993 0.9 0.093 Hercules-Glades 0.734 0.676 0.058 Mingo 0.653 0.634 0.019 Upper Buffalo 1.066 1.028 0.038

NOx - SCR

Caney Creek 0.993 0.784 0.209 Hercules-Glades 0.734 0.627 0.107 Mingo 0.653 0.611 0.042 Upper Buffalo 1.066 1.011 0.055 Class I Area Baseline 98th Percentile ∆dv NID Controlled 98th Percentile ∆dv Improvement in 98th Percentile ∆dv

Baseline 98th Percentile

∆dv

Baseline 98th Percentile

∆dv

Baseline 98th Percentile

∆dv Improvement in 98th Percentile ∆dv

Improvement in 98th Percentile ∆dv

Improvement in 98th Percentile ∆dv Class I Area

Class I Area

Class I Area LNB/OFA Controlled 98th Percentile ∆dv

LNB/OFA/SNCR 98th Percentile ∆dv

SCR Controlled 98th Percentile

∆dv Class I Area Baseline 98th Percentile ∆dv WFGD Controlled 98th

Percentile ∆dv Improvement in 98th Percentile ∆dv49,704,474 76,822,990 $ 49,704,474 117,504,668

$ 49,704,474 113,740,216

$ 49,704,474 87,354,085

$ ###########

61,085,990 95,446,859

$ 61,085,990 158,253,859

$ 61,085,990 142,724,275

$ 61,085,990 112,497,218

$ ###########

2,129,078 30,856,201

$ 2,129,078 41,746,624

$ 2,129,078 152,076,989

$ 2,129,078 59,141,051

$ ###########

4,852,239 52,174,618

$ 4,852,239 83,659,301

$ 4,852,239 255,381,025

$ 4,852,239 127,690,512

$ ###########

16,723,077 80,014,722

$ 16,723,077 156,290,438

$ 16,723,077 398,168,498

$ 16,723,077 304,055,944

$ ###########

$/dv Total Annual NID Cost

$/dv

$/dv

$/dv Total Annual LNB/OFA Cost

Total Annual LNB/OFA + SNCR Cost

Total Annual SCR Cost $/dv Total Annual WFGD Cost

### Misc Data

Design HI (MMBtu/hr) 6324 Average HI (MMBtu/hr) 4817.438

**NOx** (lb/day) (lb/hr) (lb/MMBtu) tpy Baseline NOx 46680 1945.00 0.307558507 8519.1 NOX LNB + OFA 34908.48 1454.52 0.23 NOX LNB/OFA/SNCR 30658.75 1277.448 0.202 NOX SCR 10168.99 423.708 0.067

**SO2** (lb/day) (lb/hr) (lb/MMBtu) Baseline SO2 113482 4728.417 0.74769397 20710.465 SO2 control rate Dry scrubber - NIDS 9106.56 379.44 0.06

Boiler Emission Inventory Quantities 2001 2002 2003 Average PM10 125.8 117.3 278.8 173.96667 SO2 14531.2 10962.7 9429.1 **11,641.00** NOx 5682.3 5110 4568.5 **5,120.27**

2009 2010 2011 PM10 327.52 407.81 478.48 404.60333 SO2 6551 8133.5 8618.8 **7,767.77** NOx 3619.5 4697.1 5323.6 **4,546.73**

Average number of operating hours 7752

2001 333 2002 335 2003 301

### FGR 0.292181 0.230669

OFA 0.292181 0.276803

LNB 0.261425 0.199913 LNB/OFA 0.246047 0.184535 SN'CR 0.276803 0.184535