opstat

Table 1. CY06 Paradise Fossil Plant (PAF) Plant Operating Statistics Report* Table 2. Plant Bunker Operating Statistics Report at PAF for 01/01/2006 to 10/13/2006** Table 3. Plant Bunker Operating Statistics Report at PAF for 10/14/2006 to 12/31/2006**

Parameter Unit 01 Unit 02 Unit 03 Unit 1_2 Unit 3_3 Unit 1_3 Parameter Unit 01 Unit 02 Unit 03 Unit 1_2 Unit 3_3 Unit 1_3 Parameter Unit 01 Unit 02 Unit 03 Unit 1_2 Unit 3_3 Unit 1_3 Average Hourly Gross Load (MW) 633.8 599.5 916.3 617.5 916.3 709.1 Average Hourly Gross Load (MW) 634.8 595.6 898.5 614.9 898.5 697.4 Average Hourly Gross Load (MW) 630.0 635.5 980.3 631.6 980.3 764.1 Gross Generation (MWh) 5,088,896 4,354,626 6,195,848 9,443,522 6,195,848 15,639,370 Gross Generation (MWh) 4,021,492 3,902,620 4,752,080 7,924,112 4,752,080######## Gross Generation (MWh) 1,067,404 452,006 1,443,768 1,519,410 1,443,768 2,963,178 Total Station Use (MWh) 419,755 319,305 362,852 739,060 362,852 1,101,912 Total Station Use (MWh) 331,666 283,104 289,955 614,770 289,955 904,725 Total Station Use (MWh)88,089 36,201 72,897 124,290 72,897 197,187 Net Generation (MWh) 4,669,141 4,035,321 5,832,996 8,704,462 5,832,996 14,537,458 Net Generation (MWh) 3,689,826 3,619,516 4,462,125 7,309,342 4,462,125######## Net Generation (MWh)979,315 415,805 1,370,871 1,395,120 1,370,871 2,765,991 Total Station Use Percent (percent) 8.25 7.33 5.86 7.83 5.86 7.05 Total Station Use Percent (percent) 8.25 7.25 6.10 7.76 6.10 7.14 Total Station Use Percent (percent) 8.25 8.01 5.05 8.18 5.05 6.65 Capacity Factor (percent) 82.52 70.61 61.49 76.56 61.49 69.79 Capacity Factor (percent)82.66 80.21 59.78 81.43 59.78 71.70 Capacity Factor (percent)82.00 34.72 67.89 58.36 67.89 62.64 Hours of Use (hours) 8,029 7,263 6,762 15,293 6,762 22,054 Hours of Use (hours) 6,335 6,552 5,289 12,887 5,289 18,176 Hours of Use (hours) 1,694 711 1,473 2,406 1,473 3,878 Number of Turbine Startups (No.) 6 10 21 16 21 37 Number of Turbine Startups (No.) 5 8 12 13 12 25 Number of Turbine Startups (No.) 1 2 9 3 9 12 Number of Cold Startups (No.) 5 7 16 12 16 28 Number of Cold Startups (No.) 4 5 7 9 7 16 Number of Cold Startups (No.)1 2 9 3 9 12 Gross Heat Rate (Btu/kWh) 9,042 9,426 9,819 9,220 9,822 9,458 Gross Heat Rate (Btu/kWh) 9,072 9,418 9,908 9,243 9,910 9,493 Gross Heat Rate (Btu/kWh) 8,930 9,495 9,527 9,099 9,533 9,310 Net Heat Rate with Oil (Btu/kWh) 9,855 10,172 10,430 10,003 10,433 10,175 Net Heat Rate with Oil (Btu/kWh) 9,887 10,155 10,552 10,021 10,554 10,223 Net Heat Rate with Oil (Btu/kWh) 9,733 10,322 10,033 9,909 10,039 9,974 Net Heat Rate without Oil (Btu/kWh) 9,855 10,172 10,430 10,002 10,430 10,174 Net Heat Rate without Oil (Btu/kWh) 9,887 10,155 10,552 10,020 10,552 10,221 Net Heat Rate without Oil (Btu/kWh) 9,733 10,322 10,033 9,908 10,033 9,970 Boiler Efficiency (percent) 88.26 88.31 86.04 88.27 86.04 Boiler Efficiency (percent) 88.37 88.22 85.38 88.28 85.38 Boiler Efficiency (percent) 89.19 88.30 88.23 88.30 Moisture in Fuel Boiler Loss (percent) 1.20 1.22 2.62 1.21 2.62 Moisture in Fuel Boiler Loss (percent) 1.19 1.22 3.03 1.20 3.03 Moisture in Fuel Boiler Loss (percent) 1.23 1.19 1.25 1.22 1.25 Hydrogen Loss (percent) 3.85 3.88 4.13 3.86 4.13 Hydrogen Loss (percent) 3.85 3.89 4.20 3.87 4.20 Hydrogen Loss (percent) 3.83 3.83 3.87 3.83 3.87 Dry Gas Loss (percent) 6.25 6.12 5.82 6.19 5.82 Dry Gas Loss (percent) 6.14 6.20 6.00 6.18 6.00 Dry Gas Loss (percent) 5.32 5.20 6.24 5.20 Combustibles in Fly Ash Loss (percent) 0.05 0.08 0.09 0.06 0.09 Combustibles in Fly Ash Loss (percent) 0.05 0.08 0.09 0.06 0.09 Combustibles in Fly Ash Loss (percent)0.06 0.09 0.07 0.09 Fixed Losses (percent) 0.4 0.4 1.3 0.4 1.3 Fixed Losses (percent) 0.4 0.4 1.3 0.4 1.3 Fixed Losses (percent) 0.4 0.4 1.3 0.4 1.3 Total Boiler Losses (percent) 11.74 11.69 13.96 11.73 13.96 Total Boiler Losses (percent) 11.63 11.78 14.62 11.72 14.62 Total Boiler Losses (percent) 10.81 11.70 11.77 11.70 Throttle Pressure (psig) 2,395 2,393 3,486 2,394 3,486 Throttle Pressure (psig) 2,393 2,394 3,485 2,393 3,485 Throttle Pressure (psig) 2,403 2,381 3,490 2,396 3,490 Throttle Temperature (deg F) 1,051 1,051 986 1,051 986 Throttle Temperature (deg F) 1,051 1,051 986 1,051 986 Throttle Temperature (deg F) 1,052 1,045 985 1,050 985 Reheat Temperature (deg F) 991 984 970 987 970 Reheat Temperature (deg F) 990 984 967 987 967 Reheat Temperature (deg F) 992 980 983 989 983 Condenser Back Pressure (in. Hg) 2.37 2.85 2.85 2.60 2.85 Condenser Back Pressure (in. Hg) 2.48 2.89 2.95 2.69 2.95 Condenser Back Pressure (in. Hg) 1.99 2.50 2.51 2.14 2.51 CCWInlet Temperature (deg F) 67.4 68.9 80.9 68.1 80.9 CCWInlet Temperature (deg F) 70.6 70.3 83.3 70.5 83.3 CCWInlet Temperature (deg F) 55.6 56.0 72.2 55.7 72.2 Air Preheater Air Entering Temp (deg F) 156.1 160.4 105.3 158.1 105.3 Air Preheater Air Entering Temp (deg F) 157.6 160.3 104.9 158.9 104.9 Air Preheater Air Entering Temp (deg F) 150.8 161.2 106.6 153.8 106.6 Exit Gas Temperature (deg F) 310.9 327.8 339.1 319.0 339.1 Exit Gas Temperature (deg F) 310.9 331.2 342.1 321.2 342.1 Exit Gas Temperature (deg F) 311.0 296.5 328.2 306.8 328.2 Dry Gas Loss Temperature (deg F) 74.7 79.0 102.8 76.7 102.8 Dry Gas Loss Temperature (deg F) 78.7 78.9 102.0 78.8 102.0 Dry Gas Loss Temperature (deg F) 59.9 80.0 105.6 65.8 105.6 Throttle/Feedwater flow (Klb) 36,474,54831,991,396########68,465,944######## 116,564,866 Throttle/Feedwater flow (Klb) ################################################ Throttle/Feedwater flow (Klb) 7,553,925 3,396,184################################ Superheat Attemperation (percent) 0.00 0.00 0.00 0.00 0.00 0.00 Superheat Attemperation (percent) 0.00 0.00 0.00 0.00 0.00 0.00 Superheat Attemperation (percent) 0.00 0.00 0.00 0.00 0.00 0.00 Reheat Attemperation (percent) 0.13 0.14 0.56 0.13 0.56 0.31 Reheat Attemperation (percent) 0.12 0.14 0.50 0.13 0.50 0.28 Reheat Attemperation (percent) 0.15 0.07 0.72 0.13 0.72 0.44 Makeup Water % (percent) 1.01 1.53 0.97 1.25 0.97 1.14 Makeup Water % (percent) 0.97 1.58 0.99 1.27 0.99 1.16 Makeup Water % (percent)1.18 1.07 0.94 1.15 0.94 1.04 Building Heating Steam % (percent) 0.00 0.00 0.00 0.05 0.00 0.03 Building Heating Steam % (percent) 0.00 0.07 0.00 0.03 0.00 0.02 Building Heating Steam % (percent) 0.00 0.36 0.00 0.11 0.00 0.05 Total Air (percent) 122.0 122.3 119.4 122.1 119.4 Total Air (percent) 121.8 122.2 119.0 122.0 119.0 Total Air (percent) 122.9 122.5 121.0 122.8 121.0 Total Air at Air Heater Outlet (percent) 143.0 132.3 124.6 137.9 124.6 Total Air at Air Heater Outlet (percent) 142.8 132.2 124.2 137.4 124.2 Total Air at Air Heater Outlet (percent) 143.9 132.5 126.2 140.3 126.2 Coal Burn (Klb) 3,989,922 3,568,864 6,232,164 7,558,786 6,232,164 13,790,950 Coal Burn (Klb) 3,158,014 3,194,182 5,030,366 6,352,196 5,030,366######## Coal Burn (Klb) 831,908 374,682 1,201,798 1,206,590 1,201,798 2,408,388 Combustibles in Fly Ash (percent) 2.12 3.16 3.71 2.72 3.71 3.18 Combustibles in Fly Ash (percent) 2.12 3.24 3.79 2.70 3.79 3.18 Combustibles in Fly Ash (percent) 2.54 3.39 2.91 3.39 3.18 Moisture in Coal, As Fired (percent) 11.88 11.95 21.78 11.91 21.78 16.37 Moisture in Coal, As Fired (percent) 11.80 11.96 24.08 11.88 24.08 17.27 Moisture in Coal, As Fired (percent) 12.16 11.83 12.18 12.06 12.18 12.12 Volatile Matter in Coal, As Received (percent) 34.47 34.47 32.33 34.47 32.33 33.50 Volatile Matter in Coal, As Received (percent) 34.56 34.51 31.89 34.54 31.89 33.37 Volatile Matter in Coal, As Received (percent) 34.13 34.06 34.18 34.11 34.18 34.14 Fixed Carbon in Coal, As Received (percent) 44.41 44.44 38.23 44.42 38.23 41.62 Fixed Carbon in Coal, As Received (percent) 44.51 44.44 36.84 44.47 36.84 41.10 Fixed Carbon in Coal, As Received (percent) 44.04 44.44 44.03 44.16 44.03 44.09 Ash Content of Coal, As Received (percent) 9.238 9.149 7.658 9.196 7.658 8.501 Ash Content of Coal, As Received (percent) 9.124 9.087 7.190 9.105 7.190 8.259 Ash Content of Coal, As Received (percent) 9.671 9.677 9.616 9.672 9.616 9.644 Coal Heating Value, As Received (Btu/lb) 11,532 11,501 9,762 11,518 9,762 10,724 Coal Heating Value, As Received (Btu/lb) 11,552 11,507 9,360 11,529 9,360 10,571 Coal Heating Value, As Received (Btu/lb) 11,457 11,455 11,445 11,457 11,445 11,451 Sulfur in Coal, As Received (percent) 2.730 2.704 1.364 2.717 1.364 2.106 Sulfur in Coal, As Received (percent) 2.706 2.685 1.017 2.695 1.017 1.954 Sulfur in Coal, As Received (percent) 2.819 2.866 2.817 2.834 2.817 2.825
Oil Fired (gal.) 22,765 37,941 122,114 60,706 122,114 182,820 Oil Fired (gal.) 19,607 31,371 62,114 50,978 62,114 113,092 Oil Fired (gal.) 3,243 6,485 60,000 9,728 60,000 69,728 Oil Fired Heating Value (Btu/gal.) 138,500 138,500 138,500 138,500 138,500 138,500 Oil Fired Heating Value (Btu/gal.) 138,500 138,500 138,500 138,500 138,500 138,500 Oil Fired Heating Value (Btu/gal.) 138,500 138,500 138,500 138,500 138,500 138,500 Oil Fired Sulfur Content (percent) 0.20 0.20 0.20 0.20 0.20 0.20 Oil Fired Sulfur Content (percent) 0.20 0.20 0.20 0.20 0.20 0.20 Oil Fired Sulfur Content (percent) 0.20 0.20 0.20 0.20 0.20 0.20
*Reference: DataFuser output 01/22/2007 (Plant 12MTD Operating Statistics Report at PAF for December 2006), in Excel **Reference: DataFuser output 01/31/2007 (Plant Bunker Operating Statistics Report at PAF) **Reference: DataFuser output 01/31/2007 (Plant Bunker Operating Statistics Report at PAF) file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server. TVA Environmental Technologies Note: fuel oil fired in units 1-2 was apportioned to each unit based on each boiler's proportion of the sub-plant's turbine starts. 3/26/2007

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# CEMS



# Table 1. CY 2006 CONTINUOUS EMISSION MONITORING SYSTEM (CEMS) DATA* **Paradise Fossil Plant (PAF)**



# UNIT/ **STACK SO2**  **NOx Heat Input**  **CY06 Coal (Op Stats)**  **Ratio, Tons/yr**  **lb/10^6 Btu Tons/yr**  **lb/10^6 Btu 10^6 Btu/yr**  **10^6 Btu/yr CEM/Coal**  PAF 1 15,146 0.687 13,145 0.596 44,104,732 46,013,086 0.959 PAF 2 15,805 0.693 13,040 0.571 45,638,211 41,046,749 1.112 PAF 3 52,974 1.73 9,091 0.297 61,207,491 60,839,422 1.006 PAF TOTAL 83,925 1.11 35,276 0.467 150,950,434 147,899,257 1.021

Data captured (as values) from reference: 

# SO2 **NOx Heat Input**  10^3 tons/yr lb/10^6 Btu 10^3 tons/yr lb/10^6 Btu 10^12 Btu/yr PAF1 15.146 0.687 13.145 0.596 44.104732 PAF2 15.805 0.693 13.040 0.571 45.638211 PAF3 52.974 1.731 9.091 0.297 61.207491

Data captured (as values) from reference: 

# NOx **Heat Input** tons/OS lb/10^6 Btu 10^12 Btu/OS % of CY06 PAF1 840 0.092 18.179996 41.22 PAF2 1293 0.126 20.477125 44.87 PAF3 1492 0.096 31.200077 50.97
TVA Environmental Technologies *Reference: Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey. 03/26/07 **Table 2. Annual CEMS Data**

**Table 3. Ozone Season (OS) CEMS Data Table 4. Coal vs. CEMS Data** 

Page 1 of 1

### coal_qual

**Table 1. CY06 Paradise Fossil Plant (PAF) Region-Specific Coal-Burn Quantities & Proximate Analyses***

**PAF UNITS 1-2 SOURCE**  **STATE TONS BURNED**  **IL Basin Coal PRB**  **IL Basin Coal Fines** Illinois Basin (ILB) Coal KY 3,679,729 T.Moist% = 10.9T.Moist% = 26.7T.Moist% = 24.0 Powder River Basin (PRB) Wyoming 61,011 Ash% = 8.71Ash% = 5.42Ash% = 27.4 ILB Coal Fines KY 72,451 Sul.% = 2.78Sul.% = 0.29Sul.% = 3.06 Total **3,813,191** Carb% = Carb% = Carb% = Hydr% = Hydr% = Hydr% = Nitr% = Nitr% = Nitr% = Oxy% = Oxy% = Oxy% =

BTU/lb = 11,756BTU/lb = 8,851BTU/lb = 6,673 Cl ppm = 602Cl ppm = 50Cl ppm = 158 Hg ppm = 0.1076Hg ppm = 0.105Hg ppm = 0.221

**PAF UNIT 3 SOURCE**  **STATE TONS BURNED**  Illinois Basin (ILB) Coal KY 1,318,994 **IL Basin Coal PRB**  **IL Basin Coal Fines** PRB Wyoming 1,791,422 T.Moist% = 10.9T.Moist% = 26.7T.Moist% = 24.0 ILB Coal Fines KY 60,242 Ash% = 8.71Ash% = 5.42Ash% = 27.4 Total **3,170,658** Sul.% = 2.78Sul.% = 0.29Sul.% = 3.06 Carb% = Carb% = Carb% = Hydr% = Hydr% = Hydr% = Nitr% = Nitr% = Nitr% = Oxy% = Oxy% = Oxy% =

BTU/lb = 11,756BTU/lb = 8,851BTU/lb = 6,673 Cl ppm = 602Cl ppm = 50Cl ppm = 158 Hg ppm = 0.1076Hg ppm = 0.105Hg ppm = 0.221
*Reference: Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. (CY06 coal burn, moisture, ash, sulfur, & heat contents). Note that ILB & PRB mercury (Hg) & chloride (Cl) concentrations reflect TVA's CY99 Information Collection Request (ICR) analyses (final compilation in 3-16-00 e-mail from J.D. Eady to R.W. Burbage), expressed in terms of as-received values (per 2-25-00 conversation between J.D. Eady & J.D. Lokey). ILB coal-fines dry-basis Cl & Hg values are from Excel file "PAF Fines Concentration Data.xls"
**Table 2. CY06 PAF Units 1-2 Coal Burn & Analyses** Notes:

% Wt input Region-specific coal-burn quantities and proximate analyses listed in Table 1 above were Source tons/yr As-fired Dry basis provided to TVA's Toxics Release Inventory (TRI) team for estimating emissions. These Western Bituminous (WB) 0 0% 0% data are needed due to different region-specific coal characteristics and emission factors. Eastern (App.) Bituminous (AB) 0 0% 0% PRB Subbituminous (PRB) 61,011 1.6% 1.3% Due to differences in PAF plant records, the total coal-burn quantities in Table 1 above Illinois Basin Bituminous (ILB) 3,679,729 96.5% 97.0% do not precisely match total coal-burn quantities listed in the DataFuser Operating Statistics ILB Coal Fines 72,451 1.9% 1.6% (see Table 1 in "opstat" worksheet). For PAF Units 1-2, these discrepancies were reconciled Total Burn = 3,813,191 100.0% 100.0% by apportioning region-specific coal-burn quantities between Units 1 and 2 according to the unit-specific OpStat total-burn quantities. **Analysis, % Parameter**  **(Wtd Avg)** Source % Ht input A flue-gas-desulfurization (FGD) scrubber began operation on PAF Unit 3 in October 2006. Moisture 11.40 WB 0% OpStat total coal-burn quantites for 2006 pre-FGD and post-FGD time frames are listed in Ash 9.01 AB 0% Tables 2 and 3, respectively, of the "opstat" worksheet. Monthly PAF Units 1-3 coal-fines Sulfur 2.75 PRB 1.2% burn quantities are listed in Table 4 on that worksheet. Opstat data for Unit 3 were adjusted ILB 97.7% to match Unit 3 region-specific coal-burn quantities as shown below so that emissions ILB Fines 1.1% could be estimated accounting more nearly accurately for CY06 FGD operations. Total 100.0% **Table 4. PAF Unit 3 Coal-Burn Estimates for Pre- & Post-FGD Operations** Heat value 11,613Btu/lb A. CY06 Unit 3 region-specific coal-burn total = 3,170,658tons/year (tpy)

**Table 3. CY06 PAF Unit 3 Coal Burn & Analyses** B. CY06 Unit 3 OpStat total coal burn = 3,116,082tpy C. Unit 3 ratio of region-specific total to OpStat total = 1.0175 % Wt input D. CY06 Pre-FGD Unit 3 OpStat total coal burn = 2,515,183tons Source tons/yr As-fired Dry basis E. CY06 Post-FGD Unit 3 OpStat total coal burn = 600,899tons Western Bituminous (WB) 0 0% 0% F. Adjusted CY06 Pre-FGD Unit 3 total coal burn = 2,559,235tons Eastern (App.) Bituminous (AB) 0 0% 0% G. Adjusted CY06 Post-FGD Unit 3 total coal burn = 611,423tons PRB Subbituminous (PRB) 1,791,422 56.5% 51.8% H. CY06 Pre-FGD Unit 3 PRB coal burn = 1,791,422tons Illinois Basin Bituminous (ILB) 1,318,994 41.6% 46.4% J. CY06 Post-FGD Unit 3 PRB coal burn = 0tons ILB Coal Fines 60,242 1.9% 1.8% K. CY06 Pre-FGD Unit 3 ILB coal-fines burn = 29,054tons Total Burn = 3,170,658 100.0% 100.0% L. CY06 Post-FGD Unit 3 ILB coal-fines burn = 31,188tons M. CY06 Pre-FGD Unit 3 ILB coal burn = 738,759tons **Analysis, %** N. CY06 Post-FGD Unit 3 ILB coal burn = 580,235tons **Parameter (Wtd Avg)**  Source % Ht input P. CY06 Unit 3 ILB coal-burn total = 1,318,994tons Moisture 20.08 WB 0% Ash 7.21 AB 0% Sulfur 1.38 PRB 49.9% ILB 48.8% ILB Fines 1.3% Total 100.0%

Heat value 10,018Btu/lb
**Table 3A. CY06 PAF Unit 3 Pre-FGD Coal Burn & Analyses Table 3B. CY06 PAF Unit 3 Post-FGD Coal Burn & Analyses** 

% Wt input % Wt input Source tons/yr As-fired Dry basis Source tons/yr As-fired Dry basis Western Bituminous (WB) 0 0% 0% WB 0 0% 0% Eastern (App.) Bituminous (AB) 0 0% 0% AB 0 0% 0% PRB Subbituminous (PRB) 1,791,422 70.0% 65.9% PRB 0 0.0% 0.0% Illinois Basin Bituminous (ILB) 738,759 28.9% 33.0% ILB 580,235 94.9% 95.6% ILB Coal Fines 29,054 1.1% 1.1% ILB Fines 31,188 5.1% 4.4% Total Burn = 2,559,235 100.0% 100.0% Total Burn = 611,423 100.0% 100.0%
**Analysis, % Analysis, %**  **Parameter (Wtd Avg)**  Source % Ht input **Parameter (Wtd Avg)**  Source % Ht input Moisture 22.11 WB 0% Moisture 11.57 WB 0% Ash 6.62 AB 0% Ash 9.66 AB 0% Sulfur 1.04 PRB 64.1% Sulfur 2.79 PRB 0.0% ILB 35.1% ILB 97.0% ILB Fines 0.8% ILB Fines 3.0% Total 100.0% Total 100.0%

Heat value 9,665Btu/lb Heat value 11,497Btu/lb TVA Environmental Technologies 03/26/07 **COAL ANALYSES**

**COAL ANALYSES**

Page 1 of 1

# stk_test



# Log Of Stack Testing Results*

Paradise Fossil Plant - Unit 1

Run #1 Run #2 Run #3 Run #4 Average Particulates Load Particulates Load Particulates Load Particulates Load Particulates Comments Testing Date(s)(Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu)

12/21/06 0.069 679.9 0.064 678 0.112 664.8 0.081 CY06 09/19/06 0.094 628.3 0.071 627.5 0.06 635.3 0.075 Avg = 06/13/06 0.061 687.7 0.06 682.1 0.066 681.3 0.062 0.071 03/08/06 0.071 698.9 0.063 701.8 0.066 698.1 0.067 12/14/05 0.066 696.2 0.062 695.8 0.068 692.7 0.065 CY05 09/14/05 0.101 696.7 0.086 696.1 0.082 697.1 0.090 Avg = 05/25/05 0.096 701.3 0.085 701.1 0.074 696.7 0.085 0.077 02/09/05 0.061 704 0.07 704 0.066 703 0.066 12/08/04 0.074 701 0.062 700 0.071 702 0.069 CY04 09/15/04 0.064 692 0.062 691 0.067 693 0.064 Avg = 06/26/04 0.042 676 0.054 676 0.065 676 0.053 0.066 03/04/04 0.083 708 0.074 708 0.072 709 0.076 01/06/04 0.085 700 0.066 701 0.058 701 0.07 09/10/03 0.081 635 0.089 631 0.079 631 0.083 06/17/03 0.075 684 0.093 684 0.084 651 0.084 04/15/03 0.111 665 0.108 665 0.1 664 0.106 12/1702 0.106 645 0.09 642 0.092 641 0.096 09/06/02 0.07 627.4 0.092 627.9 0.069 629.2 0.077 06/25/02 0.04 660.4 0.034 662.7 0.039 663.1 0.038 03/20/02 0.063 688.2 0.082 687.2 0.095 688.7 0.067 688.7 0.077 11/14/01 0.097 675.5 0.048 675.2 0.054 675.7 0.048 674.8 0.066 09/13/01 0.038 657.2 0.046 657.3 0.047 657.7 0.046 06/13/01 0.111 664.2 0.05 664.5 0.029 663.7 0.075 03/14/01 0.063 684.4 0.062 683 0.046 683.2 0.057 01/03/01 0.059 681 0.045 681 0.052 680 0.053 09/13/00 0.049 590 0.058 590 0.053 588 0.053 05/02/00 0.063 664 0.034 664 0.047 663 0.048 02/23/00 0.055 650 0.049 650 0.056 651 0.053 12/28/99 0.054 620 0.058 621 0.037 622 0.050 08/17/99 0.054 643 0.061 644 0.049 644 0.055 04/22/99 0.062 683 0.058 681 0.077 683 0.066 02/10/99 0.051 682 0.045 681 0.043 682 0.046 09/04/98 0.055 629 0.062 629 0.059 628 0.059 07/08/98 0.064 652 0.047 651 0.052 650 0.054 06/24/98 0.042 654 0.063 656 0.064 656 0.056 01/21/98 0.054 628 0.045 624 0.040 642 0.046 04/15/97 0.061 683 0.055 684 0.062 683 0.059 2/6/1997 0.073 688 0.039 681 0.030 681 0.047 10/1/1996 0.035 663 0.039 663 0.033 660 0.036 7/18/1996 0.044 666 0.050 666 0.041 665 0.045 05/15/96 0.053 673 0.057 674 0.058 674 0.056 02/28/96 0.057 680 0.041 678 0.033 680 0.044 12/15/95 0.042 696 0.036 696 0.045 696 0.041 8/23/1995 0.051 645 0.048 644 0.044 644 0.048 6/13/1995 0.041 660 0.039 660 0.039 660 0.040 11/08/94 0.087 658 0.047 659 0.049 659 0.061 9/1/1994 0.038 627 0.045 627 0.036 638 0.040 05/18/94 0.058 676 0.053 679 0.048 675 0.053

Page 1 of 3

# stk_test

Paradise Fossil Plant - Unit 2

Run #1 Run #2 Run #3 Run #4 Average Particulates Load Particulates Load Particulates Load Particulates Load Particulates Comments Testing Date(s)(Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu)

12/12/06 0.107 670 0.076 673.1 0.056 672.9 0.079 CY06 09/20/06 0.063 629 0.059 631.4 0.054 630.9 0.059 Avg = 07/11/06 0.064 626.4 0.064 624.7 0.067 626.1 0.065 0.069 03/09/06 0.081 660.4 0.073 658.6 0.069 645.1 0.074 12/15/05 0.072 664.5 0.064 663.1 0.063 662.5 0.066 CY05 09/15/05 0.077 658.7 0.077 660.1 0.08 659.1 0.078 Avg = 05/26/05 0.09 662.9 0.09 659.9 0.088 661.7 0.089 0.076 02/08/05 0.067 685.8 0.067 686.5 0.074 686.2 0.069 12/09/04 0.066 697 0.064 697 0.065 691 0.065 CY04 09/14/04 0.064 617 0.076 618 0.075 618 0.072 Avg = 06/24/04 0.061 637 0.058 637 0.061 635.9 0.06 0.069 03/05/04 0.077 641 0.075 641 0.083 642 0.078 12/18/03 0.073 674 0.087 675 0.076 675 0.079 09/09/03 0.083 649 0.091 647 0.064 649 0.079 05/28/03 0.083 639 0.082 639 0.086 639 0.083 04/14/03 0.108 680 0.12 678 0.101 671 0.110 12/18/02 0.097 637 0.105 637 0.102 637 0.101 09/10/02 0.051 646.4 0.048 646.1 0.046 644.2 0.048 06/26/02 0.045 642.4 0.043 640.2 0.038 642.6 0.042 03/21/02 0.067 666 0.075 666.3 0.062 667.5 0.068 11/15/01 0.043 671 0.054 671.1 0.053 671 0.050 09/11/01 0.048 603.4 0.065 601.6 0.056 605.2 0.056 06/14/01 0.042 616.3 0.043 617.9 0.04 656.1 0.042 03/20/01 0.04 682.5 0.051 683.4 0.048 685.6 0.046 11/21/00 0.082 688.7 0.096 688.8 0.07 689.1 0.083 09/12/00 0.056 661 0.069 663 0.059 666 0.061 05/03/00 0.051 676 0.041 679 0.034 674 0.042 03/07/00 0.059 692 0.023 692 0.08 676 0.054 12/21/99 0.050 676 0.047 672 0.035 685 0.044 08/18/99 0.037 574 0.045 571 0.046 572 0.043 04/29/99 0.059 619 0.062 620 0.05 632 0.057 02/09/99 0.058 620 0.048 625 0.046 621 0.051 09/05/98 0.056 630 0.056 629 0.072 629 0.061 06/23/98 0.034 652 0.042 652 0.052 652 0.043 01/22/98 0.036 627 0.043 629 0.042 629 0.040 04/16/97 0.049 664 0.046 665 0.048 662 0.048 03/05/97 0.000 662 0.04 662 0.054 663 0.031 10/02/96 0.037 673 0.033 673 0.033 671 0.034 07/26/96 0.034 652 0.047 656 0.045 656 0.042 05/16/96 0.057 674 0.058 676 0.054 675 0.056 03/11/96 0.037 662 0.045 688 0.048 676 0.043 09/08/95 0.046 620 0.049 623 0.048 625 0.048 06/14/95 0.039 645 0.041 645 0.047 642 0.042 02/24/95 0.038 658 0.029 653 0.024 652 0.030 09/01/94 0.051 653 0.105 653 0.037 658 0.064 11/09/94 0.054 659 0.037 669 0.034 673 0.042 05/18/94 0.059 667 0.049 669 0.039 663 0.049 03/03/94 0.078 664 0.065 663 0.066 666 0.070

Page 2 of 3

# stk_test

Paradise Fossil Plant - Unit 3

Run #1 Run #2 Run #3 Run #4 Average Particulates Load Particulates Load Particulates Load Particulates Load Particulates Comments Testing Date(s)(Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu) (MW) (Lbs/MMBtu)

06/14/06 0.026 1024.8 0.025 1019.5 0.026 1002.7 0.026 12/20/05 0.05 1057.9 0.038 1048.3 0.037 1048 0.042 09/07/04 0.028 1030 0.027 1021 0.028 1019 0.028 12/17/03 0.041 1022 0.035 1016 0.033 1022 0.036 09/13/02 0.033 1005.9 0.033 985.2 0.029 988.8 0.032 09/12/01 0.037 1019 0.035 1015.8 0.041 993.7 0.038 09/14/00 0.033 1001 0.038 1004 0.058 1003 0.043 9/15/1999 0.01 962 0.008 964 0.01 965 0.009 09/09/98 0.017 1048 0.023 1047 0.055 1040 0.032 05/21/96 0.010 1060 0.009 1060 0.01 1059 0.010 08/25/95 0.047 1051 0.033 1050 0.031 1040 0.037 08/30/94 0.008 1063 0.002 1051 0.003 1043 0.004

*Reference: Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
TVA Environmental Technologies 03/26/07

Page 3 of 3

# alt_fuel

**CY06 PAF ALTERNATE-FUEL DATA**

Units Reference: Wood waste burned, 10^3 tons/yr = 0 Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Pet coke burned, 10^3 tons/yr = 0 Not burned at TVA in CY06.
Tire-derived fuel, 10^3 tons/yr = 0 Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Limestone flux in boiler, 10^3 tons/yr = 0 PAF1-3 Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Used oil burned, gal/yr = 27,578 PAF1-3 Excel file "PAFoilburnedrptbegin2006.xls" in 2-7-07 e-mail from K.J. Dukes to J.D. Lokey.
Lightoff oil burned, gal/yr = 182,820 PAF 1-3 Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server.
Used boiler cleaning chemicals burned, gal/yr = 0 PAF1-3 Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server. Number of rinses per boiler cleaning = 4 per 4-5-04 email from H.G. Evans to S.S. Koss et al. (number of rinses includes passivation step)

Heat Value, Reported Total Analyte Concentration (or MDL), mg/kg Sample ID Sample Description Btu/lb Arsenic (As)Cadmium (Cd)

Minimum Detectn Limit (MDL) 2.5 0.12
Ball mill gear lube oil 19815 < MDL < MDL Ball mill mixed shop oil19339 < MDL < MDL Basment Elec. shop EPA 2000 19995 < MDL 1.3 Boiler Feed Pump Turbines 19724 < MDL < MDL Fab shop EPA 2000 19972 < MDL < MDL Fab Shop used oil19448 < MDL 0.48 Forced Draft Fans19739 < MDL 0.42 Hampton shop EPA 2000 17634 < MDL 1.3 Hampton shop used oil 14668 < MDL < MDL Hed mixed shop oil19302 < MDL 0.14 Lighting off oil 19260 < MDL < MDL Main turbine oil tank19733 < MDL < MDL MIXED SHOP OIL FROM OIL ANALYSIS 19592 < MDL < MDL OIL SPILL @ Q-1 HUT 4-15-03 11484 < MDL < MDL Pdm lab 19327 < MDL < MDL Prep plant mixed shop oil 19551 < MDL < MDL Scrubber mixed shop oil 19682 < MDL < MDL Seal Oil System 7082 < MDL < MDL Yard mixed oil 19797 < MDL < MDL
Number of samples Number of detects Mean Maximum

Page 1

# alt_fuel

*Reference: Excel file "USEDOIL_FPG Reported in CY 03.xls" in 3-4-04 e-mail from M.F. Broder to J.D. Lokey et al.; CY06 analyses not captured per TRI team decision.

**Table 2. Nominal Used-Oil Parameters***
Specific gravity 0.9g/mL Density 7.5lb/gal Ash content 0.1weight % Sulfur content 0.4weight %
*Used-oil specific gravity: 3-26-98 phone communication between D.M. Varnell & J.D. Lokey; ash content is nominal value (no data available); nominal value for TVA used-oil sulfur content provided to TRI team by S.A. Godbehere.

**Table 3. AP-42 Uncontrolled Emission Factors for Used Oil Burned in Boilers***

Criteria/Non-HAP Pollutants lb/10^3 gal Filterable particulate matter (PM_fil) 64*A (multiply factor times ash content, weight %) PM < 10-micrometers (PM10_fil) 51*A Sulfur dioxide (SO2) 147*S (multiply factor times sulfur content, weight %) Nitrogen oxides (NOx) 19 Carbon monoxide (CO) 5 Volatile organic compds (VOC) 1 Lead (Pb) 55*L (multiply factor times lead content, weight %) Carbon dioxide (CO2) 22,000

Trace-Element/HAP lb/10^3 gal Antimony (Sb) BDL BDL = Below detection limit Arsenic (As) 1.1E-01 Beryllium (Be) BDL Cadmium (Cd) 9.3E-03 Chromium (Cr) 2.0E-02 Cobalt (Co) 2.1E-04 Manganese (Mn) 6.8E-02 Nickel (Ni) 1.1E-02 Selenium (Se) BDL Phosphorus (P) ND ND = No data Hydrogen Chloride (HCl) 66*Cl (multiply factor times chlorine content, weight %)
*Reference: US EPA, AP-42, 5th Edition, Supplement B, Section 1.11, Waste Oil Combustion, 10-96
Arsenic (As) was not detected above the MDL in a recent 3-year set of TVA's used-oil analyses (CY98 & CY00-01), & TVA has no reason to expect that used oil should be contaminated with As. Therefore, the TRI team decided to consider As concentrations to be zero in accord with EPA guidance. Cd, Cr, Pb, PCB, & total halogen concentrations have been detected in used oil in that recent 3-year set of analyses, so non-detects were adjusted to be equal to 0.5 x MDL for TRI purposes. Total halogen analyses were taken to be entirely chlorine to estimate HCl emissions. No PCB emission factor is available for used-oil combustion, and none of the CY03 PAF used-oil samples were above the detection limit for PCB, so no PCB emission estimate was made.
Potential (uncontrolled) CY06 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY06 PAF used-oil burn quantities.

**Table 4. PAF CY06 Used-Oil Air Emission Estimates**

Plant Total Uncontrolled Emissn, Controlled Emissions, ton/yr Trace Element ton/yr PAF1 PAF2 Cd 2.44E-05 4.28E-07 0.00E+00

Page 2

# alt_fuel

Cr 7.41E-05 4.02E-07 0.00E+00 Co 2.90E-06 1.55E-08 0.00E+00 Pb 2.51E-04 2.49E-06 0.00E+00 Mn 9.38E-04 4.58E-06 0.00E+00 Ni 1.52E-04 6.81E-07 0.00E+00 HCl 1.63E-02 1.77E-04 0.00E+00

Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) 8.82E-02 1.75E-03 0.00E+00 PM < 10-micrometers (PM10_fil) 7.03E-02 7.28E-03 0.00E+00 Sulfur dioxide (SO2) 8.11E-01 4.49E-02 0.00E+00 Nitrogen oxides (NOx) 2.62E-01 4.01E-02 0.00E+00 Carbon monoxide (CO) 6.89E-02 2.50E-02 0.00E+00 Volatile organic compds (VOC) 1.38E-02 5.00E-03 0.00E+00
Note (1): Trace element emissions from used oil combustion are presumed to be captured by the air pollution control system with the same efficiency as those elements released from coal combustion. Note (2): Per TRI team decision, CY06 used-oil emissions were estimated using CY03 PAF used-oil analyses & CY06 used-oil burn quantities.
**Table 5. PISCES Database Elemental Analyses for Limestone***

Trace-Element Concentrations, mg/kg (dry basis) Chemical CAS Average Std. Dev

. Maximum Substance Number Median (x) (s) (max) Antimony (Sb) 7440360 0.72 42 177 1000 Arsenic (As) 7440382 1.4 2.9 3 11 Barium (Ba) 7440393 15 32 34 112 Beryllium (Be) 7440417 0.15 0.56 1.1 6 Cadmium (Cd) 7440439 0.29 0.42 0.35 1.3 Chlorine (Cl) 16887006 155 276 422 2030 Chromium (Cr) 7440473 5.3 6.8 5.2 18 Cobalt (Co) 7440484 0.5 1.4 1.7 6.2 Copper (Cu) 7440508 2.3 4.9 5.7 27 Fluorine (F) 39339850 110 155 139 526 Lead (Pb) 7439921 1.6 2.9 4.9 26 Manganese (Mn) 7439965 80 113 77 290 Mercury (Hg) 7439976 0.0085 0.039 0.13 1 Molybdenum (Mo) 7439987 2.5 13 22 61 Nickel (Ni) 7440020 3.4 6.1 8.3 43 Selenium (Se) 7782492 1.3 1.5 1.3 4.7 Silver (Ag) 7440224 0.91 1.5 1.5 5 Sulfur (S) 7704349 400 937 1080 3600 Thallium (Tl) 7440280 2.6 2.2 0.98 3.1 Vanadium (V) 7440622 5 8 6.9 28 Zinc (Zn) 7440666 17 27 37 200
Source: EPRI PISCES Database (February, 2003)
Notes: The concentrations presented in the tables were calculated using one half of the detection limits for all nondetected values. Nondetected values (represented by one half the detection limit) greater than two times the highest detected concentration
were removed from the data set before statistics were calculated.

Page 3

# alt_fuel

All data that are designated as "poor" or "unacceptable" quality in the PISCES Database were excluded from all calculations. All "unknown" quality data were included in the calculations.
Chlorine and fluorine concentrations measured in the coal and fuel oil analyses are normally reported as chloride and fluoride. However, because the forms of these elements present in the fuels are not known, the elemental designations of fluorine and chlorine have been used in reporting the concentrations in the tables.

*Reference: EPRI LARK-TRIPP Emission Estimation Model, RY2005 Version 1, 3-29-06.

**Table 6. PAF CY06 Limestone Air Emission Estimates**

Plant Total Uncontrolled Emissn, Controlled Emissions, ton/yr Trace Element ton/yr PAF1 PAF2 PAF3 Sb 0.00E+00 0.00E+00 0.00E+00 0.00E+00 As 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Ba 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Be 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Cd 0.00E+00 0.00E+00 0.00E+00 0.00E+00 HCl 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Cr 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Co 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Cu 0.00E+00 0.00E+00 0.00E+00 0.00E+00 HF 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Pb 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Mn 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Hg 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Mo 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Ni 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Se 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Ag 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Tl 0.00E+00 0.00E+00 0.00E+00 0.00E+00 V 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Zn 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Note: Trace element emissions from limestone flux addition to the boilers are presumed to be captured by the air pollution control system with the same efficiency as those elements released from coal combustion.
No limestone flux addition to PAF boilers in CY06 (per Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server).
**Table 7. Tire-Derived Fuel (TDF) Trace-Element Emission Parameters***

Uncontrolled TDF *Reference: US EPA, "Air Emissions from Scrap Tire Combustion", Emission Factor, EPA-600/R-97-115, October 1997. Trace Element lb/10^6 Btu Sb 1.24E-05 As 2.17E-04 CY03 Proximate Analyses for Allen Fossil Plant (ALF) TDF Receipts Be 2.93E-07 Cd 6.21E-06 Avg. Heat Value = 16,363 Cr 2.27E-05 Avg. SO2 Equivalent = 1.86 Pb 3.86E-04 Avg. Ash Content = 6.26

Page 4

# alt_fuel

Mn 3.40E-05 Avg. Sulfur Content = 1.56 Ni 2.05E-05 Avg. H2O Content = 1.89 Se 2.65E-05 Zn 2.08E-01 Reference: Excel file "Alternative Fuels TRI Data CY2003.xls" in 2-6-04 e-mail from S.A. Godbehere to S.S. Koss.

**Table 8. PAF CY06 TDF Air Emission Estimates** (assuming TDF is added to the boiler units in proportion to coal burned)

Plant Total Uncontrolled Emissn, Controlled Emissions, ton/yr Trace Element ton/yr PAF1 PAF2 Sb 0.00E+00 0.00E+00 0.00E+00 As 0.00E+00 0.00E+00 0.00E+00 Be 0.00E+00 0.00E+00 0.00E+00 Cd 0.00E+00 0.00E+00 0.00E+00 Cr 0.00E+00 0.00E+00 0.00E+00 Pb 0.00E+00 0.00E+00 0.00E+00 Mn 0.00E+00 0.00E+00 0.00E+00 Ni 0.00E+00 0.00E+00 0.00E+00 Se 0.00E+00 0.00E+00 0.00E+00 Zn 0.00E+00 0.00E+00 0.00E+00

Criteria/Non-HAP Pollutants Particulate matter (PM) 0.00E+00 0.00E+00 0.00E+00 Sulfur dioxide (SO2) 0.00E+00 0.00E+00 0.00E+00
Note 1: Trace element emissions from TDF combustion (if such were to occur) are presumed to be captured by the air pollution control system with the same efficiency as those elements released from coal combustion.
Note 2: No TDF-specific emission factors were available for nitrogen oxides (NOx), carbon monoxide (CO), or volatile organic compounds (VOC).
**Table 9. PAF Boiler Distillate Lightoff-Oil Emission Factors***

AP-42 Uncontrolled Emission Factors for Distillate Fuel Oil Combustion, Trace Element lb/10^12 Btu Sb 22 *Reference: US EPA'sCompilation of Air Pollutant Emission Factors As 4 5th Edition, Supplement E, 9-98 (Section 1.3, "Fuel Oil Combustion"); also, Ba 20 (for Sb, Ba, Co, Mo, and V) AP-42, Vol. I, 5th Edition, Supplement B, 10-96 Be 3 (Section 3.1, "Stationary Gas Turbines for Electricity Generation"). Cd 3 Cr 3 Co 9.1 Cu 6 Pb 9 Mn 6 Hg 3 Mo 8.4 Ni 3 Se 15 V 4.4

Page 5

# alt_fuel

Zn 4
Organic HAP (CAS Number) lb/10^3 gal Formaldehyde (50000) 0.061 Polycyclic organic matter (POM) 0.0033

Criteria/Non-HAP Pollutants lb/10^3 gal Filterable particulate matter (PM_fil) 2 PM < 10-micrometers (PM10_fil) 1 PM < 2.5-micrometers (PM2.5_fil) 0.25 Condensable PM (PM_cond) 1.3 Sulfur dioxide (SO2) 142* %S Nitrogen oxides (NOx) 24 Carbon monoxide (CO) 5 Volatile organic compds (VOC) 0.2 Sulfur trioxide (SO3) 5.7*%S
%S = weight % sulfur in fuel oil Assume all SO3 is converted to H2SO4.
**Table 10. PAF CY06 Lightoff-Oil Usage/Analyses** PAF1-3 PAF1 PAF2 PAF3 Total Usage, gallons/yr 22,765 37,941 122,114 182,820 Heat Value, Btu/gal 138,500 138,500 138,500 138,500 Sulfur Content, % 0.2 0.2 0.2 0.2

**Table 11. PAF CY06 Lightoff-Oil Air Emission Estimates, tons/yr** PAF1-3 Trace Element PAF1 PAF2 PAF3 Total Sb 3.47E-05 5.78E-05 1.86E-04 2.79E-04 As 6.31E-06 1.05E-05 3.38E-05 5.06E-05 Ba 3.15E-05 5.25E-05 1.69E-04 2.53E-04 Be 4.73E-06 7.88E-06 2.54E-05 3.80E-05 Cd 4.73E-06 7.88E-06 2.54E-05 3.80E-05 Cr 4.73E-06 7.88E-06 2.54E-05 3.80E-05 Co 1.43E-05 2.39E-05 7.70E-05 1.15E-04 Cu 9.46E-06 1.58E-05 5.07E-05 7.60E-05 Pb 1.42E-05 2.36E-05 7.61E-05 1.14E-04 Mn 9.46E-06 1.58E-05 5.07E-05 7.60E-05 Hg 4.73E-06 7.88E-06 2.54E-05 3.80E-05 Mo 1.32E-05 2.21E-05 7.10E-05 1.06E-04 Ni 4.73E-06 7.88E-06 2.54E-05 3.80E-05 Se 2.36E-05 3.94E-05 1.27E-04 1.90E-04 V 6.94E-06 1.16E-05 3.72E-05 5.57E-05 Zn 6.31E-06 1.05E-05 3.38E-05 5.06E-05
Organic HAP (CAS Number) Formaldehyde (50000) 6.94E-04 1.16E-03 3.72E-03 5.58E-03 Polycyclic organic matter (POM) 3.76E-05 6.26E-05 2.01E-04 3.02E-04

Page 6

# alt_fuel

Criteria/Non-HAP Pollutants PM_fil 2.28E-02 3.79E-02 1.22E-01 1.83E-01 PM10_fil 1.14E-02 1.90E-02 6.11E-02 9.14E-02 PM2.5_fil 2.85E-03 4.74E-03 1.53E-02 2.29E-02 PM_cond 1.48E-02 2.47E-02 7.94E-02 1.19E-01 SO2 3.23E-01 5.39E-01 1.73E+00 2.60E+00 NOx 2.73E-01 4.55E-01 1.47E+00 2.19E+00 CO 5.69E-02 9.49E-02 3.05E-01 4.57E-01 VOC 2.28E-03 3.79E-03 1.22E-02 1.83E-02 H2SO4 1.59E-02 2.65E-02 8.53E-02 1.28E-01
Distillate fuel oil is fired for lightoff during unit startup (and may also be fired at other times to ensure flame stability). During the oil-fired portion of unit startup, the electrostatic precipitators on PAF Unit 3 are not energized due to safety concerns. Consequently, lightoff-oil emission estimates reflect AP-42 uncontrolled emission factors for distillate fuel oil combustion.
**Table 12. Woodwaste (WW) Emission Parameters***

AP-42 WW(Wet Wood) Emission Factors, lb/10^6 Btu *Reference: US EPA, AP-42, 5th Edition, Supplement G, Section 1.6, Wood Residue Combustion in Boilers, 3-02 [Update 2003, revised 9-03]

Pollutant Uncontrolled Controlled

Criteria/Non-HAP Pollutants ESP Scrubber Filterable particulate matter (PM_fil) 3.30E-01 5.40E-02 6.60E-02 PM < 10-micrometers (PM10_fil) 2.90E-01 4.00E-02 6.50E-02 PM < 2.5-micrometers (PM2.5_fil) 2.50E-01 3.50E-02 6.50E-02 Condensable PM (PM_cond) 1.70E-02 1.70E-02 Sulfur dioxide (SO2) 2.50E-02 Nitrogen oxides (NOx) 2.20E-01 Carbon monoxide (CO) 6.00E-01 Volatile organic compds (VOC) 1.70E-02

Trace Element Sb 7.90E-06 As 2.20E-05 Ba 1.70E-04 Be 1.10E-06 Cd 4.10E-06 HCl 1.90E-02 Cr 2.10E-05 Co 6.50E-06 Cu 4.90E-05 Pb 4.80E-05 Mn 1.60E-03 Hg 3.50E-06 Mo 2.10E-06 Ni 3.30E-05 Se 2.80E-06 Ag 1.70E-03 V 9.80E-07 Zn 4.20E-04

Page 7

# alt_fuel

Organic HAP (CAS Number) 1,2-Dichloroethane (107062) 2.90E-05 1,2-Dichloropropane (78875) 3.30E-05 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) 8.60E-12 2,3,7,8-Tetrachlorodibenzo-p-furan (51207-31-9) 9.00E-11 2-Butanone (78933) 5.40E-06 2,4-Dinitrophenol (51285) 1.80E-07 2,4,6-Trichlorophenol (88062) < 2.20E-08 4-Nitrophenol (100027) 1.10E-07 Acetaldehyde (75070) 8.30E-04 Acetophenone (98862) 3.20E-09 Acrolein (107028) 4.00E-03 Benzene (71432) 4.20E-03 bis(2-Ethylhexyl)phthalate (117817) 4.70E-08 Bromomethane (74839) 1.50E-05 Carbon tetrachloride (56235) 4.50E-05 Chlorobenzene (108907) 3.30E-05 Chloroform (67663) 2.80E-05 Chloromethane (74873) 2.30E-05 Ethyl benzene (100414) 3.10E-05 Formaldehyde (50000) 4.40E-03 Methyl chloroform (71556) 3.10E-05 Methylene chloride (75092) 2.90E-04 Naphthalene (91203) 9.70E-05 Pentachlorophenol (87865) 5.10E-08 Phenol (108952) 5.10E-05 Propionaldehyde (123386) 6.10E-05 Styrene (100425) 1.90E-03 Tetrachloroethylene (127184) 3.80E-05 Toluene (108883) 9.20E-04 Trichloroethylene (79016) 3.00E-05 Vinyl chloride (75014) 1.80E-05 o-Xylene (95476) 2.50E-05 Polychlorinated biphenyls [PCB] (1336363): 8.15E-09 Monochlorobiphenyl 2.20E-10 Dichlorobiphenyl 7.40E-10 Trichlorobiphenyl 2.60E-09 Tetrachlorobiphenyl 2.50E-09 Pentachlorobiphenyl 1.20E-09 Hexachlorobiphenyl 5.50E-10 Heptachlorobiphenyl 6.60E-11 Decachlorobiphenyl 2.70E-10 Polychlorinated dibenzo-p-dioxins (PCDD): 1.67E-06 Tetrachlorodibenzo-p-dioxins 4.70E-10 Pentachlorodibenzo-p-dioxins 1.50E-09 Hexachlorodibenzo-p-dioxins 1.60E-06 Heptachlorodibenzo-p-dioxins 2.00E-09 Octachlorodibenzo-p-dioxins 6.60E-08 Polychlorinated dibenzo-p-furans (PCDF): 1.78E-09 Tetrachlorodibenzo-p-furans 7.50E-10 Pentachlorodibenzo-p-furans 4.20E-10

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# alt_fuel

Hexachlorodibenzo-p-furans 2.80E-10 Heptachlorodibenzo-p-furans 2.40E-10 Octachlorodibenzo-p-furans 8.80E-11 Polycyclic organic matter (POM): 4.53E-05 2-Chloronaphthalene (91-58-7) 2.40E-09 2-Methylnaphthalene (91-57-6) 1.60E-07 Acenaphthene (83-32-9) 9.10E-07 Acenaphthylene (208-96-8) 5.00E-06 Anthracene (120-12-7) 3.00E-06 Benzo(a)anthracene (56-55-3) 6.50E-08 Benzo(a)pyrene (50-32-8) 2.60E-06 Benzo(b)fluoranthene (205-99-2) 1.00E-07 Benzo(k)fluoranthene (207-08-9) 3.60E-08 Benzo(j,k)fluoranthene 1.60E-07 Benzo(e)pyrene (192-97-2) 2.60E-09 Benzo(g,h,i)perylene (191-24-2) 9.30E-08 Carbazole (86-74-8) 1.80E-06 Chrysene (218-01-9) 3.80E-08 Dibenzo(a,h)anthracene (53-70-3) 9.10E-09 Fluoranthene (206-44-0) 1.60E-06 Fluorene (86-73-7) 3.40E-06 Indeno(1,2,3,c,d)pyrene (193-39-5) 8.70E-08 Methyl anthracene 1.56E-05 Methyl anthracene emission factor (fr. AP-42 Supplemt E, 2-99) is not contained in AP-42 Supplemt G. Perylene (198-55-0) 5.20E-10 Supplemt E factor, in lb/(ton of moist, as-fired wood waste), was converted to lb/10^6 Btu per 4500 Btu/lb moist WW. Phenanthrene (85-01-8) 7.00E-06 Pyrene (129-00-0) 3.70E-06 Polycyclic aromatic compounds (PAC) 4.54E-06

**Table 13. PAF CY06 WW Air Emission Estimates** (assuming WWis added to the boiler units in proportion to coal burned)
Species Controlled Emissions, ton/yr PAF1 PAF2 PAF3 Criteria/Non-HAP Pollutants PM_fil 0.00E+00 0.00E+00 0.00E+00 PM10_fil 0.00E+00 0.00E+00 0.00E+00 PM2.5_fil 0.00E+00 0.00E+00 0.00E+00 PM_cond 0.00E+00 0.00E+00 0.00E+00 SO2 0.00E+00 0.00E+00 0.00E+00 NOx 0.00E+00 0.00E+00 0.00E+00 CO 0.00E+00 0.00E+00 0.00E+00 VOC 0.00E+00 0.00E+00 0.00E+00 Trace Element Sb 0.00E+00 0.00E+00 0.00E+00 As 0.00E+00 0.00E+00 0.00E+00 Ba 0.00E+00 0.00E+00 0.00E+00 Be 0.00E+00 0.00E+00 0.00E+00 Cd 0.00E+00 0.00E+00 0.00E+00 Cr 0.00E+00 0.00E+00 0.00E+00 Co 0.00E+00 0.00E+00 0.00E+00 Cu 0.00E+00 0.00E+00 0.00E+00

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Pb 0.00E+00 0.00E+00 0.00E+00 Mn 0.00E+00 0.00E+00 0.00E+00 Mo 0.00E+00 0.00E+00 0.00E+00 Ni 0.00E+00 0.00E+00 0.00E+00 Se 0.00E+00 0.00E+00 0.00E+00 Ag 0.00E+00 0.00E+00 0.00E+00 V 0.00E+00 0.00E+00 0.00E+00 Zn 0.00E+00 0.00E+00 0.00E+00 HCl 0.00E+00 0.00E+00 0.00E+00 Hg 0.00E+00 0.00E+00 0.00E+00
Organic HAP (CAS Number) 1,2-Dichloroethane (107062) 0.00E+00 0.00E+00 0.00E+00 1,2-Dichloropropane (78875) 0.00E+00 0.00E+00 0.00E+00 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) 0.00E+00 0.00E+00 0.00E+00 2,3,7,8-Tetrachlorodibenzo-p-furan (51207-31-9) 0.00E+00 0.00E+00 0.00E+00 2-Butanone (78933) 0.00E+00 0.00E+00 0.00E+00 2,4-Dinitrophenol (51285) 0.00E+00 0.00E+00 0.00E+00 2,4,6-Trichlorophenol (88062) 0.00E+00 0.00E+00 0.00E+00 4-Nitrophenol (100027) 0.00E+00 0.00E+00 0.00E+00 Acetaldehyde (75070) 0.00E+00 0.00E+00 0.00E+00 Acetophenone (98862) 0.00E+00 0.00E+00 0.00E+00 Acrolein (107028) 0.00E+00 0.00E+00 0.00E+00 Benzene (71432) 0.00E+00 0.00E+00 0.00E+00 bis(2-Ethylhexyl)phthalate (117817) 0.00E+00 0.00E+00 0.00E+00 Bromomethane (74839) 0.00E+00 0.00E+00 0.00E+00 Carbon tetrachloride (56235) 0.00E+00 0.00E+00 0.00E+00 Chlorobenzene (108907) 0.00E+00 0.00E+00 0.00E+00 Chloroform (67663) 0.00E+00 0.00E+00 0.00E+00 Chloromethane (74873) 0.00E+00 0.00E+00 0.00E+00 Ethyl benzene (100414) 0.00E+00 0.00E+00 0.00E+00 Formaldehyde (50000) 0.00E+00 0.00E+00 0.00E+00 Methyl chloroform (71556) 0.00E+00 0.00E+00 0.00E+00 Methylene chloride (75092) 0.00E+00 0.00E+00 0.00E+00 Naphthalene (91203) 0.00E+00 0.00E+00 0.00E+00 Pentachlorophenol (87865) 0.00E+00 0.00E+00 0.00E+00 Phenol (108952) 0.00E+00 0.00E+00 0.00E+00 Propionaldehyde (123386) 0.00E+00 0.00E+00 0.00E+00 Styrene (100425) 0.00E+00 0.00E+00 0.00E+00 Tetrachloroethylene (127184) 0.00E+00 0.00E+00 0.00E+00 Toluene (108883) 0.00E+00 0.00E+00 0.00E+00 Trichloroethylene (79016) 0.00E+00 0.00E+00 0.00E+00 Vinyl chloride (75014) 0.00E+00 0.00E+00 0.00E+00 o-Xylene (95476) 0.00E+00 0.00E+00 0.00E+00 Polychlorinated biphenyls [PCB] (1336363): 0.00E+00 0.00E+00 0.00E+00 Polychlorinated dibenzo-p-dioxins (PCDD): 0.00E+00 0.00E+00 0.00E+00 Polychlorinated dibenzo-p-furans (PCDF): 0.00E+00 0.00E+00 0.00E+00 Polycyclic organic matter (POM): 0.00E+00 0.00E+00 0.00E+00 2-Chloronaphthalene (91-58-7) 0.00E+00 0.00E+00 0.00E+00 2-Methylnaphthalene (91-57-6) 0.00E+00 0.00E+00 0.00E+00 Acenaphthene (83-32-9) 0.00E+00 0.00E+00 0.00E+00

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# alt_fuel

Acenaphthylene (208-96-8) 0.00E+00 0.00E+00 0.00E+00 Anthracene (120-12-7) 0.00E+00 0.00E+00 0.00E+00 Benzo(a)anthracene (56-55-3) 0.00E+00 0.00E+00 0.00E+00 Benzo(a)pyrene (50-32-8) 0.00E+00 0.00E+00 0.00E+00 Benzo(b)fluoranthene (205-99-2) 0.00E+00 0.00E+00 0.00E+00 Benzo(k)fluoranthene (207-08-9) 0.00E+00 0.00E+00 0.00E+00 Benzo(j,k)fluoranthene 0.00E+00 0.00E+00 0.00E+00 Benzo(e)pyrene (192-97-2) 0.00E+00 0.00E+00 0.00E+00 Benzo(g,h,i)perylene (191-24-2) 0.00E+00 0.00E+00 0.00E+00 Carbazole (86-74-8) 0.00E+00 0.00E+00 0.00E+00 Chrysene (218-01-9) 0.00E+00 0.00E+00 0.00E+00 Dibenzo(a,h)anthracene (53-70-3) 0.00E+00 0.00E+00 0.00E+00 Fluoranthene (206-44-0) 0.00E+00 0.00E+00 0.00E+00 Fluorene (86-73-7) 0.00E+00 0.00E+00 0.00E+00 Indeno(1,2,3,c,d)pyrene (193-39-5) 0.00E+00 0.00E+00 0.00E+00 Methyl anthracene 0.00E+00 0.00E+00 0.00E+00 Perylene (198-55-0) 0.00E+00 0.00E+00 0.00E+00 Phenanthrene (85-01-8) 0.00E+00 0.00E+00 0.00E+00 Pyrene (129-00-0) 0.00E+00 0.00E+00 0.00E+00 Polycyclic aromatic compounds (PAC) 0.00E+00 0.00E+00 0.00E+00
**Table 14. CY06 Emission Estimates for PAF Evaporation/Combustion of Used EDTA Boiler Cleaning Chemical Solutions***
**PAF Unit 1 Generic EDTA Analysis & Emission Estimates 

All-Composite Mass Control Stack Concentration, Inputs, Efficiency, Emissns, 

# Component mg/L lb % tons Aluminum(Al) 

# 0.8 0.00E+00 90 0.00E+00 Arsenic(As) 

# nd** * 97.09 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 98.72 0.00E+00 Boron (B) 

# 3.8 0.00E+00 90 0.00E+00 Cadmium(Cd) 

# 0.11 0.00E+00 95.17 0.00E+00 Calcium(Ca) 

# 56.4 0.00E+00 90 0.00E+00 Chromium(Cr) 

# 2.7 0.00E+00 98.50 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 98.52 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 98.99 0.00E+00 Iron(Fe) 

# 1772 0.00E+00 94 0.00E+00 Lead(Pb) 

# 2.0 0.00E+00 97.26 0.00E+00 Magnesium(Mg) 

# 7.4 0.00E+00 90 0.00E+00 Manganese(Mn) 

# 14.0 0.00E+00 98.65 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 97.43 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 98.76 0.00E+00 Phosphorus as(PO4

# ) 

# 102 0.00E+00 90 0.00E+00 Potassium(K) 

# 0.4 0.00E+00 90 0.00E+00 Selenium(Se) 

# nd*** 88.03 0.00E+00 Silicon(Si) 

# 1.8 0.00E+00 90 0.00E+00 Silver(Ag) 

# 0.28 0.00E+00 95.90 0.00E+00 Sodium(Na) 

# 8.2 0.00E+00 90 0.00E+00 Sulfur asSulfate 

# 10.2 0.00E+00 90 0.00E+00 Tin(Sn) 

# 0.6 0.00E+00 90 0.00E+00

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# alt_fuel

Titanium(Ti) 

# 0.4 0.00E+00 90 0.00E+00 Vanadium(V) 

# 0.2 0.00E+00 98.73 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.44 0.00E+00 pH 9.3 Spec Gravity 1.04 %residual EDTA 4.6%

***nd = none detected EDTA Drain Vol = gallons No.. of Rinses = 4 Volume Burned = 0 gallons
*PAF burned no used-boiler-cleaning chemicals in CY06, per Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server.
Note: First-flush EDTA drain volumes (boiler-tube-volume capacity) for PAF Units 1-2 (142,000 gallons/boiler) and PAF Unit 3 (143,000 gal) were taken from Excel file "boilercleaning methods vs. plants.xls" in 6-22-98 e-mail from E.W. Zizvari to J.D. Lokey et al.
**Note: "All-composite" concentrations listed above for RCRA analytes (As, Ba, Cd, Cr, Pb, Se, and Ag) reflect TCLP Extract analyses for used ethylenediamine-tetraacetic-acid (EDTA) boiler-cleaning chemicals (EDTA + rinsate) from 11-11-02 Colbert Fossil Plant (COF) Unit 1 boiler cleaning. These analyses were deemed "worst-case" for all plants' boiler cleanings (3-13-03 e-mail from S.S. Koss to R.W. Burbage et al.). Concentrations listed for non-RCRA analytes were derived from Hydrochem grab-sample "drain" analyses for 11-11-02 COF Unit 1 boiler cleaning. Since the "drain" analyses reflect "first-flush" EDTA drain only and do not include rinsate, these concentrations were adjusted to account for volume (EDTA drain + rinsate) that was burned, assuming that the rinsate contributed negligible quantities of metals.
EDTA is not a TRI chemical. EDTA is decomposed to molecular nitrogen (N2), carbon dioxide (CO2), and water, according to literature reports. During burns of used EDTA boiler-cleaning chemicals in coal-fired boilers, trace elements contained in the solution are reported to be distributeduniformly among the ash particles formed during coal combustion. Stack tests at oil- & coal-fired boilers during burn/evaporation of used boilercleaning chemicals reported by Sisson and Lee (1972) indicated that metals in the EDTA solution are collected by air-pollution-control (APC) equipment at the same efficiency as applies during normal operation. Tests in an oil-fired boiler equipped with cyclone-type mechanical collectors found 88% of Cu, 94% of Fe, and 90% of Ni injected in the solution were retained in the boiler system. The portion retained in the boiler was assumed to go in ash streams to land disposal. Air emissions due to CY06 burn/evaporation of used boiler-cleaning chemicals in the PAF boiler units (had such occurred) were estimated using coal-fired APC control efficiencies where available, and were otherwise based on conservative values in the Excel file "Boiler cleanings EDTA Evaporated.xls" in 6-22-98 e-mail from E.W. Zizvari to J.D. Lokey,
as revised per conversations 7-7-98 and 7-8-98 (renamed "Blr_clean_EDTA_Evap.xls") & included in 7-8-98 e-mail from J.D. Lokey to T.A. Burnett, et al. These efficiencies are supported as being conservative estimates by the following references:
(1) "Incineration Safely Disposes of Chemical Cleaning Solvents", by A.B. Sisson & G.V. Lee, presented at the 34th Annual Meeting of American Power Conference, Chicago, IL, April 18-20, 1972.
(2) "Evaporation in Boiler Furnace", technical literature provided to E.W. Zizvari by representative of Hydrochem Industrial Services, Inc., Crossville, IL.
(3) "Evaporation Process for Chemical Waste Disposal", technical literature provided by Halliburton Services, Duncan, OK.

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**CY06 PAF ALTERNATE-FUEL DATA**

Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.

Not burned at TVA in CY06.
Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Excel file "PAFoilburnedrptbegin2006.xls" in 2-7-07 e-mail from K.J. Dukes to J.D. Lokey.
Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server.

Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server. per 4-5-04 email from H.G. Evans to S.S. Koss et al. (number of rinses includes passivation step)

**Table 1. CY03 PAF Used-Oil Analyses***
Reported Total Analyte Concentration (or MDL), mg/kg Adjusted Total Analyte Concentration, mg/kg Chromium (Cr) Lead (Pb) As Cd Cr Pb

1.2 1.2

< MDL < MDL 0 0.06 0.6 0.6 < MDL 8.5 0 0.06 0.6 8.5 < MDL 1.7 0 1.3 0.6 1.7 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 2 11 0 0.48 2 11 < MDL 3.1 0 0.42 0.6 3.1 < MDL 2.3 0 1.3 0.6 2.3 < MDL < MDL 0 0.06 0.6 0.6 < MDL 6.7 0 0.14 0.6 6.7 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 1.4 2.9 0 0.06 1.4 2.9 < MDL < MDL 0 0.06 0.6 0.6 < MDL < MDL 0 0.06 0.6 0.6 < MDL 3.2 0 0.06 0.6 3.2

19 19 19 19 0 5 2 8 0 0.236 0.716 2.42 0 1.3 2 11

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*Reference: Excel file "USEDOIL_FPG Reported in CY 03.xls" in 3-4-04 e-mail from M.F. Broder to J.D. Lokey et al.; CY06 analyses not captured per TRI team decision.

*Used-oil specific gravity: 3-26-98 phone communication between D.M. Varnell & J.D. Lokey; ash content is nominal value (no data available); nominal value for TVA used-oil sulfur content provided to TRI team by S.A. Godbehere.

**Table 3. AP-42 Uncontrolled Emission Factors for Used Oil Burned in Boilers***

*A (multiply factor times ash content, weight %)
*S (multiply factor times sulfur content, weight %)

*L (multiply factor times lead content, weight %)

*Cl (multiply factor times chlorine content, weight %)
*Reference: US EPA, AP-42, 5th Edition, Supplement B, Section 1.11, Waste Oil Combustion, 10-96
Arsenic (As) was not detected above the MDL in a recent 3-year set of TVA's used-oil analyses (CY98 & CY00-01), & TVA has no reason to expect that used oil should be contaminated with As. Therefore, the TRI team decided to consider As concentrations to be zero in accord with EPA guidance. Cd, Cr, Pb, PCB, & total halogen concentrations have been detected in used oil in that recent 3-year set of analyses, so non-detects were adjusted to be equal to 0.5 x MDL for TRI purposes. Total halogen analyses were taken to be entirely chlorine to estimate HCl emissions. No PCB emission factor is available for used-oil combustion, and none of the CY03 PAF used-oil samples were above the detection limit for PCB, so no PCB emission estimate was made.
Potential (uncontrolled) CY06 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY06 PAF used-oil burn quantities.

**Table 4. PAF CY06 Used-Oil Air Emission Estimates**

PAF1-3 % of PAF3 PAF3 Total Total Emissns 4.59E-07 8.87E-07 0.0013

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# alt_fuel

4.43E-07 8.46E-07 0.0002 1.48E-08 3.03E-08 0.00003 2.08E-06 4.58E-06 0.0007 4.97E-06 9.55E-06 0.0011 8.68E-07 1.55E-06 0.0003 5.56E-03 5.73E-03 0.0011

1.19E-03 2.94E-03 0.0001 4.96E-03 1.22E-02 0.0006 3.45E-01 3.90E-01 0.0007 4.15E-02 8.16E-02 0.0005 4.40E-02 6.89E-02 0.0055 8.79E-03 1.38E-02 0.0050
Note (1): Trace element emissions from used oil combustion are presumed to be captured by the air pollution control system with the same efficiency as those elements released from coal combustion. Note (2): Per TRI team decision, CY06 used-oil emissions were estimated using CY03 PAF used-oil analyses & CY06 used-oil burn quantities.
**Table 5. PISCES Database Elemental Analyses for Limestone***

Trace-Element Concentrations, mg/kg (dry basis) Number of Data Non- Limestone Minimum x+3s Points Detects H2O, % 0.0025 573 32 17 1 0.66 11.9 39 13 (taken from SHF Title V Permit Application, 12-3-96) 1.3 134 34 10 0.00015 3.86 37 19 0.01 1.47 42 12 22 1542 27 2 0.57 22.4 36 4 0.15 6.5 29 13 1 22 35 9 3 572 32 7 0.1 17.6 41 6 0.02 344 38 0 0.002 0.429 58 36 0.04 79 27 10 1.5 31 33 8 0.086 5.4 42 22 0.91 6 15 13 75 4177 15 1 0.08 5.14 7 2 1.8 28.7 33 6 0.01 138 30 2

Notes: The concentrations presented in the tables were calculated using one half of the detection limits for all nondetected values. Nondetected values (represented by one half the detection limit) greater than two times the highest detected concentration

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# alt_fuel

All data that are designated as "poor" or "unacceptable" quality in the PISCES Database were excluded from all calculations.

Chlorine and fluorine concentrations measured in the coal and fuel oil analyses are normally reported as chloride and fluoride. However, because the forms of these elements present in the fuels are not known, the elemental designations of fluorine and

**Table 6. PAF CY06 Limestone Air Emission Estimates**

PAF1-3 % of PAF3 Total Total Emissns 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Note: Trace element emissions from limestone flux addition to the boilers are presumed to be captured by the air pollution

No limestone flux addition to PAF boilers in CY06 (per Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server).
**Table 7. Tire-Derived Fuel (TDF) Trace-Element Emission Parameters***

*Reference: US EPA, "Air Emissions from Scrap Tire Combustion",

EPA-600/R-97-115, October 1997.

CY03 Proximate Analyses for Allen Fossil Plant (ALF) TDF Receipts
Btu/lb (as rec'd) 16,678Btu/lb (dry) lb SO2/10^6 Btu % (as received) 6.38% (dry)

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% (as received) 1.58% (dry) %

Reference: Excel file "Alternative Fuels TRI Data CY2003.xls" in 2-6-04 e-mail from S.A. Godbehere to S.S. Koss.

**Table 8. PAF CY06 TDF Air Emission Estimates** (assuming TDF is added to the boiler units in proportion to coal burned)

Controlled Emissions, ton/yr PAF1-3 % of PAF1 PAF3 Total Total Emissns 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00

0.00E+00 0.00E+00 0.00 0.00E+00 0.00E+00 0.00
Note 1: Trace element emissions from TDF combustion (if such were to occur) are presumed to be captured by the air pollution control system with

Note 2: No TDF-specific emission factors were available for nitrogen oxides (NOx), carbon monoxide (CO), or volatile organic compounds (VOC).
**Table 9. PAF Boiler Distillate Lightoff-Oil Emission Factors***

Compilation of Air Pollutant Emission Factors(AP-42), Vol. I, 5th Edition, Supplement E, 9-98 (Section 1.3, "Fuel Oil Combustion"); also, (for Sb, Ba, Co, Mo, and V) AP-42, Vol. I, 5th Edition, Supplement B, 10-96 (Section 3.1, "Stationary Gas Turbines for Electricity Generation").

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% of PAF1 Total Emissns 0.10 0.001 0.00 0.01 0.01 0.001 0.01 0.00 0.002 0.001 0.01 0.00 0.001 0.00 0.001 0.000

1.13 0.12

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0.001 0.001 0.000 0.003 0.002 0.002 0.01 0.002 0.001
Distillate fuel oil is fired for lightoff during unit startup (and may also be fired at other times to ensure flame stability). During the oil-fired portion of unit startup, the electrostatic precipitators on PAF Unit 3 are not energized due to safety concerns. Consequently, lightoff-oil emission estimates reflect AP-42 uncontrolled emission factors for distillate fuel oil combustion.
**Table 12. Woodwaste (WW) Emission Parameters***

*Reference: US EPA, AP-42, 5th Edition, Supplement G, Section 1.6, Wood Residue Combustion in Boilers, 3-02 [Update 2003, revised 9-03]

Basis for AP-42 Supplement E (2-99) emission factors:

WWHeating Value = 4500Btu/lb WWH2O Content = 50weight %

CY99 & CY03 WWAnalyses** No. of samples CY03 WWHeat = 4372Btu/lb (as-received) 27 CY03 WWTotal H2O = 45.66weight % 27

CY03 WWAsh = 5.66wt. % (as-received) 27 CY03 WWSulfur = 0.06wt. % (as-received) 27

CY99 WWChlorine = 0.151wt. % (dry) 7 CY99 WWMercury = 0.029ppm (dry) 7

**References: Excel file "CY99 BACA Wood analyses.xls" in 1-10-00 e-mail from T.V. Bramlett to S.M. Deberry, as modified per 3-29-00 e-mail from T.V. Bramlett to J.D. Lokey (CY99 Hg & Cl analyses); Excel file "Alternative Fuels TRI Data CY2003.xls" downloaded 2-10-04 from "envshr" drive. drive. (CY03 analyses for sawdust burned at Colbert Fossil Plant [COF]).
Uncontrolled Emission Factors based on CY99/CY03 analyses:

lb/ton WWas firedlb/10^6 Btu SO2 2.21 0.252 HCl 1.69 0.194 Hg 3.19E-05 3.65E-06
Note controlled filterable PM/PM10/PM2.5 emission factors for wood-fired boilers with electrostatic-precipitator (ESP) PM control system

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were used for PAF Unit 3, and corresponding emission factors for boilers with wet-scrubber PM control system were used for PAF Units 1-2.

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Methyl anthracene emission factor (fr. AP-42 Supplemt E, 2-99) is not contained in AP-42 Supplemt G. Supplemt E factor, in lb/(ton of moist, as-fired wood waste), was converted to lb/10^6 Btu per 4500 Btu/lb moist WW.

**Table 13. PAF CY06 WW Air Emission Estimates** (assuming WWis added to the boiler units in proportion to coal burned)

PAF1-3 % of PAF1 Total Total Emissns

0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.000 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00

0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00

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0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00

0.00E+00 #DIV/0! 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 #DIV/0! 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.0000 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00

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0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 #DIV/0! 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 #DIV/0! 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00 0.00E+00 0.00
**Table 14. CY06 Emission Estimates for PAF Evaporation/Combustion of Used EDTA Boiler Cleaning Chemical Solutions***
**PAF Unit 2 Generic EDTA Analysis & Emission Estimates 

All-Composite Mass Control Stack Concentration, Inputs, Efficiency, Emissns, 

# Component mg/L lb % tons Aluminum(Al) 

# 0.8 0.00E+00 90 0.00E+00 Arsenic(As) 

# nd** * 97.00 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 98.67 0.00E+00 Boron (B) 

# 3.8 0.00E+00 90 0.00E+00 Cadmium(Cd) 

# 0.11 0.00E+00 95.09 0.00E+00 Calcium(Ca) 

# 56.4 0.00E+00 90 0.00E+00 Chromium(Cr) 

# 2.7 0.00E+00 98.47 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 98.48 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 98.97 0.00E+00 Iron(Fe) 

# 1772 0.00E+00 94 0.00E+00 Lead(Pb) 

# 2.0 0.00E+00 97.18 0.00E+00 Magnesium(Mg) 

# 7.4 0.00E+00 90 0.00E+00 Manganese(Mn) 

# 14.0 0.00E+00 98.62 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 97.37 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 98.74 0.00E+00 Phosphorus as(PO4

# ) 

# 102 0.00E+00 90 0.00E+00 Potassium(K) 

# 0.4 0.00E+00 90 0.00E+00 Selenium(Se) 

# nd*** 88.03 0.00E+00 Silicon(Si) 

# 1.8 0.00E+00 90 0.00E+00 Silver(Ag) 

# 0.28 0.00E+00 95.90 0.00E+00 Sodium(Na) 

# 8.2 0.00E+00 90 0.00E+00 Sulfur asSulfate 

# 10.2 0.00E+00 90 0.00E+00 Tin(Sn) 

# 0.6 0.00E+00 90 0.00E+00

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Titanium(Ti) 

# 0.4 0.00E+00 90 0.00E+00 Vanadium(V) 

# 0.2 0.00E+00 98.70 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.42 0.00E+00 pH 9.3 Spec Gravity 1.04 %residual EDTA 4.6%

***nd = none detected EDTA Drain Vol = gallons No.. of Rinses = 4 Volume Burned = 0 gallons
*PAF burned no used-boiler-cleaning chemicals in CY06, per Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server.
Note: First-flush EDTA drain volumes (boiler-tube-volume capacity) for PAF Units 1-2 (142,000 gallons/boiler) and PAF Unit 3 (143,000 gal) were taken from Excel file "boilercleaning methods vs. plants.xls"

**Note: "All-composite" concentrations listed above for RCRA analytes (As, Ba, Cd, Cr, Pb, Se, and Ag) reflect TCLP Extract analyses for used ethylenediamine-tetraacetic-acid (EDTA) boiler-cleaning chemicals (EDTA + rinsate) from 11-11-02 Colbert Fossil Plant (COF) Unit 1 boiler cleaning. These analyses were deemed "worst-case" for all plants' boiler cleanings (3-13-03 e-mail from S.S. Koss to R.W. Burbage et al.). Concentrations listed for non-RCRA analytes were derived from Hydrochem grab-sample "drain" analyses for 11-11-02 COF Unit 1 boiler cleaning. Since the "drain" analyses reflect "first-flush" EDTA drain only and do not include rinsate, these concentrations were adjusted to account for volume (EDTA drain + rinsate) that was burned, assuming that the rinsate contributed negligible quantities of metals.
EDTA is not a TRI chemical. EDTA is decomposed to molecular nitrogen (N2), carbon dioxide (CO2), and water, according to literature reports. During burns of used EDTA boiler-cleaning chemicals in coal-fired boilers, trace elements contained in the solution are reported to be distributeduniformly among the ash particles formed during coal combustion. Stack tests at oil- & coal-fired boilers during burn/evaporation of used boilercleaning chemicals reported by Sisson and Lee (1972) indicated that metals in the EDTA solution are collected by air-pollution-control (APC) equipment at the same efficiency as applies during normal operation. Tests in an oil-fired boiler equipped with cyclone-type mechanical collectors found 88% of Cu, 94% of Fe, and 90% of Ni injected in the solution were retained in the boiler system. The portion retained in the boiler was assumed to go in ash streams to land disposal. Air emissions due to CY06 burn/evaporation of used boiler-cleaning chemicals in the PAF boiler units (had such occurred) were estimated using coal-fired APC control efficiencies where available, and were otherwise based on conservative values in the Excel file "Boiler cleanings EDTA Evaporated.xls" in 6-22-98 e-mail from E.W. Zizvari to J.D. Lokey,
as revised per conversations 7-7-98 and 7-8-98 (renamed "Blr_clean_EDTA_Evap.xls") & included in 7-8-98 e-mail from J.D. Lokey to T.A. Burnett, et al. These efficiencies are supported as being conservative estimates by the following references:
(1) "Incineration Safely Disposes of Chemical Cleaning Solvents", by A.B. Sisson & G.V. Lee, presented at the 34th Annual Meeting of American Power Conference, Chicago, IL, April 18-20, 1972.
(2) "Evaporation in Boiler Furnace", technical literature provided to E.W. Zizvari by representative of Hydrochem Industrial Services, Inc., Crossville, IL.
(3) "Evaporation Process for Chemical Waste Disposal", technical literature provided by Halliburton Services, Duncan, OK.

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Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.

Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.

Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server.

Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server.

PCB in Used Oil, ppm Total Halogens in Used Oil, ppm Reported (or MDL) Adjusted Reported (or MDL) Adjusted

1 200

< MDL 0.5 600 600 < MDL 0.5 < MDL 100 < MDL 0.5 300 300 < MDL 0.5 < MDL 100 < MDL 0.5 200 200 < MDL 0.5 400 400 < MDL 0.5 < MDL 100 < MDL 0.5 200 200 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 200 200 < MDL 0.5 < MDL 100 < MDL 0.5 < MDL 100 < MDL 0.5 300 300

19 19 0 7 0.5 179 0.5 600

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*Used-oil specific gravity: 3-26-98 phone communication between D.M. Varnell & J.D. Lokey; ash content is nominal value (no data available); nominal value for TVA used-oil sulfur content provided to TRI team by S.A. Godbehere.

Arsenic (As) was not detected above the MDL in a recent 3-year set of TVA's used-oil analyses (CY98 & CY00-01), & TVA has no reason to expect that used oil should be contaminated with As. Therefore, the TRI team decided to consider As concentrations to be zero in accord with EPA guidance. Cd, Cr, Pb, PCB, & total halogen concentrations have been detected in used oil in that

Potential (uncontrolled) CY06 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY06 PAF used-oil burn quantities.

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Note (1): Trace element emissions from used oil combustion are presumed to be captured by the air pollution control system with the same efficiency as those elements released from coal combustion.

(taken from SHF Title V Permit Application, 12-3-96)

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No limestone flux addition to PAF boilers in CY06 (per Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server).

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*Reference: US EPA, AP-42, 5th Edition, Supplement G, Section 1.6, Wood Residue Combustion in Boilers, 3-02 [Update 2003, revised 9-03]

No. of samples

to S.M. Deberry, as modified per 3-29-00 e-mail from T.V. Bramlett to J.D. Lokey (CY99 Hg & Cl analyses); Excel file "Alternative Fuels TRI Data CY2003.xls" downloaded 2-10-04 from "envshr" drive.

Note controlled filterable PM/PM10/PM2.5 emission factors for wood-fired boilers with electrostatic-precipitator (ESP) PM control system

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were used for PAF Unit 3, and corresponding emission factors for boilers with wet-scrubber PM control system were used for PAF Units 1-2.

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Supplemt E factor, in lb/(ton of moist, as-fired wood waste), was converted to lb/10^6 Btu per 4500 Btu/lb moist WW.

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**PAF Unit 3 Generic EDTA Analysis & Emission Estimates 
All-Composite Mass Control Stack Concentration, Inputs, Efficiency, Emissns, 

# Component mg/L lb % tons Aluminum(Al) 

# 0.8 0.00E+00 90 0.00E+00 Arsenic(As) 

# nd** * 98.77 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 99.39 0.00E+00 Boron (B) 

# 3.8 0.00E+00 90 0.00E+00 Cadmium(Cd) 

# 0.11 0.00E+00 97.05 0.00E+00 Calcium(Ca) 

# 56.4 0.00E+00 90 0.00E+00 Chromium(Cr) 

# 2.7 0.00E+00 99.06 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 99.20 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 99.34 0.00E+00 Iron(Fe) 

# 1772 0.00E+00 94 0.00E+00 Lead(Pb) 

# 2.0 0.00E+00 98.70 0.00E+00 Magnesium(Mg) 

# 7.4 0.00E+00 90 0.00E+00 Manganese(Mn) 

# 14.0 0.00E+00 99.17 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 98.46 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 99.10 0.00E+00 Phosphorus as(PO4

# ) 

# 102 0.00E+00 90 0.00E+00 Potassium(K) 

# 0.4 0.00E+00 90 0.00E+00 Selenium(Se) 

# nd*** 70.64 0.00E+00 Silicon(Si) 

# 1.8 0.00E+00 90 0.00E+00 Silver(Ag) 

# 0.28 0.00E+00 97.39 0.00E+00 Sodium(Na) 

# 8.2 0.00E+00 90 0.00E+00 Sulfur asSulfate 

# 10.2 0.00E+00 90 0.00E+00 Tin(Sn) 

# 0.6 0.00E+00 90 0.00E+00

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Titanium(Ti) 

# 0.4 0.00E+00 90 0.00E+00 Vanadium(V) 

# 0.2 0.00E+00 99.42 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.88 0.00E+00 pH 9.3 Spec Gravity 1.04 %residual EDTA 4.6%

***nd = none detected EDTA Drain Vol = gallons No.. of Rinses = 4 Volume Burned = 0 gallons
*PAF burned no used-boiler-cleaning chemicals in CY06, per Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server.
Note: First-flush EDTA drain volumes (boiler-tube-volume capacity) for PAF Units 1-2 (142,000 gallons/boiler) and PAF Unit 3 (143,000 gal) were taken from Excel file "boilercleaning methods vs. plants.xls"

**Note: "All-composite" concentrations listed above for RCRA analytes (As, Ba, Cd, Cr, Pb, Se, and Ag) reflect TCLP Extract analyses for used ethylenediamine-tetraacetic-acid (EDTA) boiler-cleaning chemicals (EDTA + rinsate) from 11-11-02 Colbert Fossil Plant (COF) Unit 1 boiler cleaning. These analyses were deemed "worst-case" for all plants' boiler cleanings (3-13-03 e-mail from S.S. Koss to R.W. Burbage et al.). Concentrations listed for non-RCRA analytes were derived from Hydrochem grab-sample "drain" analyses for 11-11-02 COF Unit 1 boiler cleaning. Since the "drain" analyses reflect "first-flush" EDTA drain only and do not include rinsate, these concentrations were adjusted to account for volume (EDTA drain + rinsate) that was burned, assuming that the rinsate contributed negligible quantities of metals.

(1) "Incineration Safely Disposes of Chemical Cleaning Solvents", by A.B. Sisson & G.V. Lee, presented at the 34th Annual Meeting of American Power Conference, Chicago, IL, April 18-20, 1972.

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**PAF Units 1-3 Plant Total EDTA Burn Emission Estimates***

Amount Stack in Solution, Emissns, Component lb tons Aluminum(Al) 

# 0.00E+00 0.00E+00 Arsenic(As) 

# 0.00E+00 0.00E+00 Barium(Ba) 

# 0.00E+00 0.00E+00 Boron (B) 

# 0.00E+00 0.00E+00 Cadmium(Cd) 

# 0.00E+00 0.00E+00 Calcium(Ca) 

# 0.00E+00 0.00E+00 Chromium(Cr) 

# 0.00E+00 0.00E+00 Cobalt(Co) 

# 0.00E+00 0.00E+00 Copper(Cu) 

# 0.00E+00 0.00E+00 Iron(Fe) 

# 0.00E+00 0.00E+00 Lead(Pb) 

# 0.00E+00 0.00E+00 Magnesium(Mg) 

# 0.00E+00 0.00E+00 Manganese(Mn) 

# 0.00E+00 0.00E+00 Molybdenum(Mo) 

# 0.00E+00 0.00E+00 Nickel(Ni) 

# 0.00E+00 0.00E+00 Phosphorus as(PO4

# ) 

# 0.00E+00 0.00E+00 Potassium(K) 

# 0.00E+00 0.00E+00 Selenium(Se) 

# 0.00E+00 0.00E+00 Silicon(Si) 

# 0.00E+00 0.00E+00 Silver(Ag) 

# 0.00E+00 0.00E+00 Sodium(Na) 

# 0.00E+00 0.00E+00 Sulfur asSulfate 

# 0.00E+00 0.00E+00 Tin(Sn) 

# 0.00E+00 0.00E+00

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Titanium(Ti) 

# 0.00E+00 0.00E+00 Vanadium(V) 

# 0.00E+00 0.00E+00 Zinc(Zn) 

# 0.00E+00 0.00E+00

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Page 59PAF1_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.106 ILB COAL HEAT INPUT (10^12 BTU/YR) = 45.67 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.687 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.596 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 10.90 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL ASH (AS-FIRED) % WT (AVG) 8.71 CY06 FUEL & CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,756 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.78 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 1,942,353 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 18.60 MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (total) = 0.412 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.85E+06 1.06E+05 94.28 2420 738 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.41E+05 7.21E+04 70.07 1646 502 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.02E+05 3.82E+04 62.54 871 266 NA NA Condensable PM (PM_cond) NA 2.00E+04 457 139 NA NA Sulfur dioxide (SO2) NA 4.49E+06 6.87E+05 84.71 14801 4780 36577 8351 Nitrogen oxides (NOx) NA 1.40E+06 5.96E+05 57.53 12784 4148 NA NA Carbon monoxide (CO) NA 2.13E+04 2.13E+04 0.00 486 148 Volatile organic compounds (VOC) NA 4.68E+03 4.68E+03 0.00 107 32.6 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.61E+05 5.15E+04 68.11 1176 358 Ammonia (NH3)(6) NA 4.15E+02 4.15E-03 99.999 9.47E-05 2.89E-05 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 2.00E+00 1.52E+02 1.50E+00 99.01 3.42E-02 1.04E-02 53.1 22.34 Arsenic (As) 1.10E+01 8.34E+02 2.55E+01 96.94 5.82E-01 1.77E-01 828 28.90 Beryllium (Be) 2.00E+00 1.52E+02 2.81E+00 98.14 6.42E-02 1.96E-02 82.6 35.68 Cadmium (Cd) 5.00E-01 3.79E+01 2.43E+00 93.59 5.55E-02 1.69E-02 90.8 18.18 Chromium (Cr) 1.60E+01 1.21E+03 1.94E+01 98.40 4.42E-01 1.35E-01 701 20.76 Cobalt (Co) 3.70E+00 2.80E+02 4.43E+00 98.42 1.01E-01 3.09E-02 154 24.18 Lead (Pb) 1.40E+01 1.06E+03 3.00E+01 97.18 6.84E-01 2.08E-01 992 27.46 Manganese (Mn) 2.90E+01 2.20E+03 3.01E+01 98.63 6.87E-01 2.09E-01 1080 21.40 Nickel (Ni) 1.90E+01 1.44E+03 1.88E+01 98.69 4.29E-01 1.31E-01 708 17.52

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.76E+02 5.27E+04 1.58E+03 97.00 3.61E+01 1.10E+01 72,160 -0.01 Hydrogen fluoride (HF) 9.20E+01 7.34E+03 4.41E+02 94.00 1.01E+01 3.07E+00 20,119 0.005 Mercury (Hg) 8.00E-02 6.06E+00 3.25E+00 46.37 7.43E-02 2.26E-02 148 0.004 Selenium (Se) 1.70E+00 1.29E+02 1.55E+01 88.00 3.53E-01 1.08E-01 706 0.000007

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 2.03E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 5.94E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.43E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.64E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.51E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 7.08E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.57E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 2.08E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 5.25E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.51E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 7.31E-02 2.23E-02 146 0.001 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.74E-02 8.35E-03 54.8 0.001 Acrolein (107028) NA 1.90E+00 0.00E+00 4.34E-02 1.32E-02 86.8 0.001 Benzene (71432) NA 3.90E+00 0.00E+00 8.91E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 6.39E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.65E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 8.22E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 2.03E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.51E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.65E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.21E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.83E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.51E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.32E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.51E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 2.06E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.83E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 5.94E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.12E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 9.36E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.57E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.74E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.39E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.51E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 8.22E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.42E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 7.54E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.43E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.34E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.60E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 9.59E-03 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 3.88E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 7.08E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.67E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.88E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.03E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6)NA 3.90E-07 0.00E+00 8.91E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.53E+00 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.55E+03 1.17E-01 1.78E-05

Notes:

(1)CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.

(2)Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.

(3)Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).

(4)Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.

(5)"Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.

(6)Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF1_ILB_fines

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.106 ILB COAL HEAT INPUT (10^12 BTU/YR) = 0.51 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILLINOIS-BASIN (ILB) FINES SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.687 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.596 BASED ON: ILB COAL FINES H2O (AS-FIRED) % WT (AVG) 24.00 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL FINES ASH (AS-FIRED) % WT (AVG) 27.40 CY06 FUEL & CEMS DATA(1) ILB FINES HEAT VALUE (AS-FIRED) BTU/LB (AVG) 6,673 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB FINES TRACE-ELEMENT CONCENTRATNS(2) ILB COAL FINES SULFUR (AS-FIRED)% WT (AVG) 3.06 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FINES FIRED (AS-FIRED) TONS 38,243 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 10.14 AVERAGE ILB FINES UNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (total) = 0.412 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.03E+07 1.06E+05 98.97 27.1 738 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.33E+06 7.21E+04 94.60 18.4 502 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 5.65E+05 3.82E+04 93.24 9.74 266 NA NA Condensable PM (PM_cond) NA 2.00E+04 5.10 139 NA NA Sulfur dioxide (SO2) NA 8.71E+06 6.87E+05 92.12 321 4780 36577 8351 Nitrogen oxides (NOx) NA 2.47E+06 5.96E+05 75.89 252 4148 NA NA Carbon monoxide (CO) NA 3.75E+04 3.75E+04 0.00 9.56 261 Volatile organic compounds (VOC) NA 8.24E+03 8.24E+03 0.00 2.10 57.4 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 3.13E+05 9.99E+04 68.11 25.5 695 Ammonia (NH3)(6) NA 4.15E+02 4.15E-03 99.999 1.06E-06 2.89E-05 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 1.25E+01 1.42E+03 2.09E+00 99.85 5.33E-04 1.45E-02 0.83 22.38 Arsenic (As) 4.18E+01 4.76E+03 2.62E+01 99.45 6.67E-03 1.82E-01 9.48 28.95 Beryllium (Be) 3.50E+00 3.99E+02 1.24E+00 99.69 3.16E-04 8.62E-03 0.41 35.75 Cadmium (Cd) 1.10E+01 1.25E+03 5.93E+00 99.53 1.51E-03 4.13E-02 2.48 18.21 Chromium (Cr) 7.98E+01 9.09E+03 2.31E+01 99.75 5.89E-03 1.61E-01 9.32 20.80 Cobalt (Co) 1.90E+01 2.16E+03 5.57E+00 99.74 1.42E-03 3.88E-02 2.15 24.23 Lead (Pb) 3.20E+01 3.64E+03 2.04E+01 99.44 5.21E-03 1.42E-01 7.56 27.51 Manganese (Mn) 4.40E+01 5.01E+03 1.77E+01 99.65 4.51E-03 1.23E-01 7.08 21.44 Nickel (Ni) 8.05E+01 9.17E+03 2.01E+01 99.78 5.13E-03 1.40E-01 8.46 17.56

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 1.58E+02 1.85E+04 5.55E+02 97.00 1.42E-01 3.86E+00 283 0.04 Hydrogen fluoride (HF) 9.20E+01 1.10E+04 6.62E+02 94.00 1.69E-01 4.61E+00 338 0.006 Mercury (Hg) 2.21E-01 2.52E+01 1.48E+01 41.40 3.76E-03 1.03E-01 7.53 0.002 Selenium (Se) 7.88E+01 8.97E+03 1.08E+03 88.00 2.75E-01 7.49E+00 550 0.001

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 2.27E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 6.64E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.83E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.84E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.81E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 7.91E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 5.10E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 2.32E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 5.87E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.81E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 8.17E-04 2.23E-02 1.63 0.004 Acetophenone (98862) NA 1.20E+00 0.00E+00 3.06E-04 8.35E-03 0.61 -0.004 Acrolein (107028) NA 1.90E+00 0.00E+00 4.85E-04 1.32E-02 0.97 0.006 Benzene (71432) NA 3.90E+00 0.00E+00 9.95E-04 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 7.15E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 4.08E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 9.19E-04 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 2.27E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.81E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 4.08E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.35E-04 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 2.04E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.81E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.48E-04 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.81E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 2.30E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 2.04E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 6.64E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.25E-04 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 1.05E-06 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 5.10E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 3.06E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.56E-04 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.81E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 9.19E-04 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.58E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 8.42E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.83E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.85E-04 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.79E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 1.07E-04 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 4.34E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 7.91E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.86E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 3.22E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.38E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.95E-11 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.71E-02 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.55E+03 1.30E-03 1.78E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF1_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.106 PRB COAL HEAT INPUT (10^12 BTU/YR) = 0.57 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.687 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.596 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 26.70 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW PRB COAL ASH (AS-FIRED) % WT (AVG) 5.42 CY06 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,851 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.29 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 32,205 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY MEDIAN PRB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.53E+06 1.06E+05 93.08 30.2 738 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.99E+05 7.21E+04 63.78 20.5 502 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.42E+04 3.82E+04 54.68 10.9 266 NA NA Condensable PM (PM_cond) NA 2.00E+04 5.70 139 NA NA Sulfur dioxide (SO2) NA 5.73E+05 5.73E+05 0.00 23.6 3990 36577 8351 Nitrogen oxides (NOx) NA 9.60E+05 5.96E+05 37.93 109 4148 NA NA Carbon monoxide (CO) NA 2.82E+04 2.82E+04 0.00 8.05 197 Volatile organic compounds (VOC) NA 6.21E+03 6.21E+03 0.00 1.77 43.2 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 2.70E+03 8.60E+02 68.11 0.245 5.98 Ammonia (NH3)(6) NA 4.15E+02 3.11E+00 99.25 8.86E-04 2.16E-02 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 1.50E-01 1.24E+01 3.49E-01 97.19 9.96E-05 2.43E-03 0.1548 22.27 Arsenic (As) 1.20E+00 9.94E+01 4.92E+00 95.05 1.40E-03 3.42E-02 1.99 28.83 Beryllium (Be) 2.50E-01 2.07E+01 3.88E-01 98.13 1.11E-04 2.70E-03 0.1425 35.60 Cadmium (Cd) 1.10E-01 9.11E+00 1.31E+00 85.61 3.74E-04 9.12E-03 0.612 18.13 Chromium (Cr) 4.30E+00 3.56E+02 1.06E+01 97.02 3.03E-03 7.39E-02 4.80 20.71 Cobalt (Co) 1.60E+00 1.33E+02 3.01E+00 97.72 8.59E-04 2.10E-02 1.304 24.13 Lead (Pb) 3.20E+00 2.65E+02 1.15E+01 95.66 3.28E-03 8.00E-02 4.76 27.40 Manganese (Mn) 1.40E+01 1.16E+03 2.30E+01 98.02 6.55E-03 1.60E-01 10.30 21.35 Nickel (Ni) 2.90E+00 2.40E+02 8.72E+00 96.37 2.49E-03 6.07E-02 4.10 17.48

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.82E+01 5.81E+03 1.74E+02 97.00 4.97E-02 1.21E+00 99.3 0.06 Hydrogen fluoride (HF) 5.20E+01 4.53E+03 2.72E+02 94.00 7.76E-02 1.89E+00 155.1 0.004 Mercury (Hg) 6.00E-02 4.97E+00 4.71E+00 5.26 1.34E-03 3.28E-02 2.68 -0.002 Selenium (Se) 7.40E-01 6.13E+01 1.84E+00 97.00 5.24E-04 1.28E-02 1.048 0.001

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 2.54E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 7.41E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 4.28E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 2.05E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 3.14E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 8.84E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 5.70E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 2.59E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 6.56E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 3.14E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 9.12E-04 2.23E-02 1.82 -0.001 Acetophenone (98862) NA 1.20E+00 0.00E+00 3.42E-04 8.35E-03 0.684 0.001 Acrolein (107028) NA 1.90E+00 0.00E+00 5.42E-04 1.32E-02 1.083 -0.003 Benzene (71432) NA 3.90E+00 0.00E+00 1.11E-03 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 7.98E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 4.56E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 1.03E-03 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 2.54E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 3.14E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 4.56E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.51E-04 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 2.28E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 3.14E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.65E-04 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 3.14E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 2.57E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 2.28E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 7.41E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.40E-04 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 1.17E-06 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 5.70E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 3.42E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.74E-04 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 3.14E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 1.03E-03 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.77E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 9.41E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 4.28E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 5.42E-04 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 2.00E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 1.20E-04 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 4.85E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 8.84E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 2.08E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 3.59E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.78E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 1.11E-10 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.91E-02 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.55E+03 1.46E-03 1.78E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF1

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.106 COAL HEAT INPUT (10^12 BTU/YR) = 46.75 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILB/FINES/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.687 DATE: 03/26/07 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.596 COAL H2O (AS-FIRED) % WT (AVG) 11.40 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW CY06 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 9.01 ILB/FINES/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,613 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 2.75 PM SO2 NOx MAX OF CY01-CY03 PM STACK TEST DATA(4) COAL FIRED TONS 2,012,801 0.11 1.2 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 17.7 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY WEIGHTED-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.94E+06 1.06E+05 94.54 2478 738 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.52E+05 7.21E+04 71.42 1685 502 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.07E+05 3.82E+04 64.24 892 266 NA NA Condensable PM (PM_cond) NA 2.00E+04 467 139 QA/QC: NA NA Sulfur dioxide (SO2) NA 4.49E+06 6.87E+05 84.71 15146 4780 0 36577 8351 Nitrogen oxides (NOx) NA 1.41E+06 5.96E+05 57.72 13145 4148 0 NA NA Carbon monoxide (CO) NA 2.15E+04 2.15E+04 0.00 503 150 Volatile organic compounds (VOC) NA 4.74E+03 4.74E+03 0.00 111 33.0 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.61E+05 5.14E+04 68.11 1202 358 Ammonia (NH3)(6) NA 4.15E+02 4.20E-02 99.99 9.82E-04 2.92E-04

PM Trace-Element HAP Antimony (Sb) 2.15E+00 1.64E+02 1.49E+00 99.09 3.48E-02 1.04E-02 Arsenic (As) 1.14E+01 8.68E+02 2.53E+01 97.09 5.90E-01 1.76E-01 Beryllium (Be) 2.00E+00 1.53E+02 2.77E+00 98.19 6.46E-02 1.92E-02 Cadmium (Cd) 6.66E-01 5.08E+01 2.45E+00 95.17 5.74E-02 1.71E-02 Chromium (Cr) 1.69E+01 1.29E+03 1.93E+01 98.50 4.51E-01 1.34E-01 Cobalt (Co) 3.92E+00 2.99E+02 4.43E+00 98.52 1.04E-01 3.08E-02 Lead (Pb) 1.42E+01 1.08E+03 2.96E+01 97.26 6.93E-01 2.06E-01 Manganese (Mn) 2.90E+01 2.22E+03 2.99E+01 98.65 6.98E-01 2.08E-01 Nickel (Ni) 1.98E+01 1.51E+03 1.87E+01 98.76 4.37E-01 1.30E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.59E+02 5.17E+04 1.55E+03 97.00 3.63E+01 1.08E+01 Hydrogen fluoride (HF) 9.15E+01 7.35E+03 4.41E+02 94.00 1.03E+01 3.07E+00 Mercury (Hg) 8.20E-02 6.26E+00 3.40E+00 45.75 7.94E-02 2.36E-02 Selenium (Se) 2.94E+00 2.25E+02 2.69E+01 88.03 6.28E-01 1.87E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 2.08E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 6.08E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.51E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.68E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.57E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 7.25E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.67E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 2.13E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 5.38E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.57E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 7.48E-02 2.23E-02 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.80E-02 8.35E-03 Acrolein (107028) NA 1.90E+00 0.00E+00 4.44E-02 1.32E-02 Benzene (71432) NA 3.90E+00 0.00E+00 9.12E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 6.54E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.74E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 8.41E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 2.08E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.57E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.74E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.24E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.87E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.57E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.36E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.57E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 2.10E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.87E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 6.08E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.15E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 9.58E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.67E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.80E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.43E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.57E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 8.41E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.45E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 7.71E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.51E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.44E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.64E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 9.82E-03 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 3.97E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 7.25E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.71E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.95E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.10E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.12E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.56E+00 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.55E+03 1.19E-01 1.78E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF2_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.110 ILB COAL HEAT INPUT (10^12 BTU/YR) = 40.85 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.693 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.571 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 10.90 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL ASH (AS-FIRED) % WT (AVG) 8.71 CY06 FUEL & CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,756 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.78 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 1,737,376 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 18.60 MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (total) = 0.445 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.85E+06 1.10E+05 94.08 2240 763 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.41E+05 7.46E+04 69.03 1523 519 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.02E+05 3.95E+04 61.25 806 275 NA NA Condensable PM (PM_cond) NA 2.00E+04 408 139 NA NA Sulfur dioxide (SO2) NA 4.49E+06 6.93E+05 84.58 15445 4820 36577 8351 Nitrogen oxides (NOx) NA 1.40E+06 5.71E+05 59.28 12682 3977 NA NA Carbon monoxide (CO) NA 2.13E+04 2.13E+04 0.00 434 148 Volatile organic compounds (VOC) NA 4.68E+03 4.68E+03 0.00 95.6 32.6 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.61E+05 5.15E+04 68.11 1052 358 Ammonia (NH3)(6) NA 4.36E+02 4.36E-03 99.999 8.90E-05 3.03E-05 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 2.00E+00 1.52E+02 1.53E+00 98.99 3.13E-02 1.07E-02 46.68 25.34 Arsenic (As) 1.10E+01 8.34E+02 2.62E+01 96.85 5.36E-01 1.83E-01 722.70 32.58 Beryllium (Be) 2.00E+00 1.52E+02 2.92E+00 98.07 5.96E-02 2.03E-02 71.59 39.96 Cadmium (Cd) 5.00E-01 3.79E+01 2.47E+00 93.48 5.05E-02 1.72E-02 80.06 20.70 Chromium (Cr) 1.60E+01 1.21E+03 1.97E+01 98.37 4.03E-01 1.37E-01 616 23.59 Cobalt (Co) 3.70E+00 2.80E+02 4.54E+00 98.38 9.27E-02 3.16E-02 135 27.39 Lead (Pb) 1.40E+01 1.06E+03 3.08E+01 97.10 6.29E-01 2.14E-01 868 31.00 Manganese (Mn) 2.90E+01 2.20E+03 3.07E+01 98.60 6.27E-01 2.14E-01 950 24.29 Nickel (Ni) 1.90E+01 1.44E+03 1.91E+01 98.67 3.90E-01 1.33E-01 625 19.96

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.76E+02 5.27E+04 1.58E+03 97.00 3.23E+01 1.10E+01 64,545 -0.01 Hydrogen fluoride (HF) 9.20E+01 7.34E+03 4.41E+02 94.00 9.00E+00 3.07E+00 17,996 0.005 Mercury (Hg) 8.00E-02 6.06E+00 3.12E+00 48.58 6.37E-02 2.17E-02 127 0.03 Selenium (Se) 1.70E+00 1.29E+02 1.55E+01 88.00 3.16E-01 1.08E-01 632 -0.000004

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.82E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 5.31E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.06E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.47E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.25E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 6.33E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.08E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 1.86E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 4.70E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 2.25E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 6.54E-02 2.23E-02 131 0.001 Acetophenone (98862) NA 1.20E+00 2.45E-02 8.35E-03 49.0 0.001 Acrolein (107028) NA 1.90E+00 3.88E-02 1.32E-02 77.6 0.001 Benzene (71432) NA 3.90E+00 7.97E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 5.72E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 3.27E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 7.35E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 1.82E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 2.25E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 3.27E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 1.08E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 1.63E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 2.25E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 1.18E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 2.25E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 1.84E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 1.63E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 5.31E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 1.00E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 8.37E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 4.08E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 2.45E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 1.25E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 2.25E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 7.35E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.27E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 6.74E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.06E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 3.88E-02 1.32E-02 Styrene (100425) NA 7.00E-01 1.43E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 8.58E-03 2.92E-03 Toluene (108883) NA 1.70E+00 3.47E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 6.33E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 1.49E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 2.57E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.71E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 7.97E-09 2.71E-09 Organic HAP Total 6.69E+01 1.37E+00 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.64E+03 1.08E-01 1.84E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF2_ILB_fines

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.110 ILB COAL HEAT INPUT (10^12 BTU/YR) = 0.46 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILLINOIS-BASIN (ILB) FINES SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.693 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.571 BASED ON: ILB COAL FINES H2O (AS-FIRED) % WT (AVG) 24.00 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL FINES ASH (AS-FIRED) % WT (AVG) 27.40 CY06 FUEL & CEMS DATA(1) ILB FINES HEAT VALUE (AS-FIRED) BTU/LB (AVG) 6,673 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB FINES TRACE-ELEMENT CONCENTRATNS(2) ILB COAL FINES SULFUR (AS-FIRED)% WT (AVG) 3.06 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FINES FIRED (AS-FIRED) TONS 34,208 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 10.14 AVERAGE ILB FINESUNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (total) = 0.445 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.03E+07 1.10E+05 98.93 25.0 763 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.33E+06 7.46E+04 94.41 17.0 519 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 5.65E+05 3.95E+04 93.01 9.01 275 NA NA Condensable PM (PM_cond) NA 2.00E+04 4.57 139 NA NA Sulfur dioxide (SO2) NA 8.71E+06 6.93E+05 92.05 335 4820 36577 8351 Nitrogen oxides (NOx) NA 2.47E+06 5.71E+05 76.89 250 3977 NA NA Carbon monoxide (CO) NA 3.75E+04 3.75E+04 0.00 8.55 261 Volatile organic compounds (VOC) NA 8.24E+03 8.24E+03 0.00 1.88 57.4 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 3.13E+05 9.99E+04 68.11 22.8 695 Ammonia (NH3)(6) NA 4.36E+02 4.36E-03 99.999 9.95E-07 3.03E-05 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 1.25E+01 1.42E+03 2.13E+00 99.85 4.87E-04 1.49E-02 0.73 25.38 Arsenic (As) 4.18E+01 4.76E+03 2.69E+01 99.43 6.14E-03 1.87E-01 8.28 32.63 Beryllium (Be) 3.50E+00 3.99E+02 1.29E+00 99.68 2.93E-04 8.95E-03 0.35 40.03 Cadmium (Cd) 1.10E+01 1.25E+03 6.04E+00 99.52 1.38E-03 4.20E-02 2.18 20.74 Chromium (Cr) 7.98E+01 9.09E+03 2.35E+01 99.74 5.37E-03 1.64E-01 8.20 23.63 Cobalt (Co) 1.90E+01 2.16E+03 5.70E+00 99.74 1.30E-03 3.97E-02 1.89 27.43 Lead (Pb) 3.20E+01 3.64E+03 2.10E+01 99.42 4.79E-03 1.46E-01 6.61 31.05 Manganese (Mn) 4.40E+01 5.01E+03 1.80E+01 99.64 4.11E-03 1.25E-01 6.22 24.33 Nickel (Ni) 8.05E+01 9.17E+03 2.04E+01 99.78 4.66E-03 1.42E-01 7.46 19.99

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 1.58E+02 1.85E+04 5.55E+02 97.00 1.27E-01 3.86E+00 253 0.04 Hydrogen fluoride (HF) 9.20E+01 1.10E+04 6.62E+02 94.00 1.51E-01 4.61E+00 302 0.007 Mercury (Hg) 2.21E-01 2.52E+01 1.41E+01 43.89 3.22E-03 9.83E-02 6.45 0.03 Selenium (Se) 7.88E+01 8.97E+03 1.08E+03 88.00 2.46E-01 7.49E+00 492 0.002

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.03E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 5.93E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.42E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.64E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.51E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 7.08E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.57E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 2.08E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.25E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 2.51E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 7.30E-04 2.23E-02 100.0000 Acetophenone (98862) NA 1.20E+00 2.74E-04 8.35E-03 100.000 Acrolein (107028) NA 1.90E+00 4.34E-04 1.32E-02 100.0000 Benzene (71432) NA 3.90E+00 8.90E-04 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 6.39E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 3.65E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 8.22E-04 2.51E-02 Bromomethane (74839) NA 8.90E-01 2.03E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 2.51E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 3.65E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 1.21E-04 3.69E-03 Chloroform (67663) NA 8.00E-01 1.83E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 2.51E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 1.32E-04 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 2.51E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 2.05E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 1.83E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 5.93E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 1.12E-04 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 9.36E-07 2.85E-05 Iodomethane (74884) NA 2.00E+00 4.57E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 2.74E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 1.39E-04 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 2.51E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 8.22E-04 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.42E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 7.53E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.42E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 4.34E-04 1.32E-02 Styrene (100425) NA 7.00E-01 1.60E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 9.59E-05 2.92E-03 Toluene (108883) NA 1.70E+00 3.88E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 7.08E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 1.67E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 2.88E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.02E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 8.90E-11 2.71E-09 Organic HAP Total 6.69E+01 1.53E-02 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.64E+03 1.21E-03 1.84E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF2_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.110 PRB COAL HEAT INPUT (10^12 BTU/YR) = 0.51 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.693 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.571 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 26.70 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW PRB COAL ASH (AS-FIRED) % WT (AVG) 5.42 CY06 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,851 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.29 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 28,806 0.11 1.2 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY MEDIAN PRB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.53E+06 1.10E+05 92.84 28.0 763 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.99E+05 7.46E+04 62.53 19.0 519 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.42E+04 3.95E+04 53.11 10.1 275 NA NA Condensable PM (PM_cond) NA 2.00E+04 5.10 139 NA NA Sulfur dioxide (SO2) NA 5.73E+05 5.73E+05 0.00 24.6 3990 36577 8351 Nitrogen oxides (NOx) NA 9.60E+05 5.71E+05 40.49 108 3977 NA NA Carbon monoxide (CO) NA 2.82E+04 2.82E+04 0.00 7.20 197 Volatile organic compounds (VOC) NA 6.21E+03 6.21E+03 0.00 1.58 43.2 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 2.70E+03 8.60E+02 68.11 0.219 5.98 Ammonia (NH3)(6) NA 4.36E+02 3.27E+00 99.25 8.33E-04 2.27E-02 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 1.50E-01 1.24E+01 3.57E-01 97.13 9.10E-05 2.48E-03 0.136 25.28 Arsenic (As) 1.20E+00 9.94E+01 5.06E+00 94.91 1.29E-03 3.52E-02 1.74 32.52 Beryllium (Be) 2.50E-01 2.07E+01 4.03E-01 98.05 1.03E-04 2.80E-03 0.124 39.89 Cadmium (Cd) 1.10E-01 9.11E+00 1.33E+00 85.37 3.40E-04 9.28E-03 0.539 20.65 Chromium (Cr) 4.30E+00 3.56E+02 1.08E+01 96.96 2.76E-03 7.54E-02 4.23 23.54 Cobalt (Co) 1.60E+00 1.33E+02 3.09E+00 97.67 7.87E-04 2.15E-02 1.14 27.34 Lead (Pb) 3.20E+00 2.65E+02 1.18E+01 95.54 3.01E-03 8.22E-02 4.16 30.94 Manganese (Mn) 1.40E+01 1.16E+03 2.35E+01 97.98 5.98E-03 1.63E-01 9.06 24.25 Nickel (Ni) 2.90E+00 2.40E+02 8.86E+00 96.31 2.26E-03 6.17E-02 3.62 19.92

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.82E+01 5.81E+03 1.74E+02 97.00 4.44E-02 1.21E+00 88.8 0.06 Hydrogen fluoride (HF) 5.20E+01 4.53E+03 2.72E+02 94.00 6.94E-02 1.89E+00 138.7 0.006 Mercury (Hg) 6.00E-02 4.97E+00 4.71E+00 5.26 1.20E-03 3.28E-02 2.40 0.001 Selenium (Se) 7.40E-01 6.13E+01 1.84E+00 97.00 4.69E-04 1.28E-02 0.938 0.0004

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.27E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 6.63E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.82E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.84E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.80E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 7.90E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 5.10E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 2.32E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.86E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 2.80E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 8.16E-04 2.23E-02 100.000 Acetophenone (98862) NA 1.20E+00 3.06E-04 8.35E-03 100.000 Acrolein (107028) NA 1.90E+00 4.84E-04 1.32E-02 100.000 Benzene (71432) NA 3.90E+00 9.94E-04 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 7.14E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 4.08E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 9.18E-04 2.51E-02 Bromomethane (74839) NA 8.90E-01 2.27E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 2.80E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 4.08E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 1.35E-04 3.69E-03 Chloroform (67663) NA 8.00E-01 2.04E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 2.80E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 1.48E-04 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 2.80E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 2.29E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 2.04E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 6.63E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 1.25E-04 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.05E-06 2.85E-05 Iodomethane (74884) NA 2.00E+00 5.10E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 3.06E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 1.56E-04 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 2.80E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 9.18E-04 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.58E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 8.41E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.82E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 4.84E-04 1.32E-02 Styrene (100425) NA 7.00E-01 1.78E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.07E-04 2.92E-03 Toluene (108883) NA 1.70E+00 4.33E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 7.90E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 1.86E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 3.21E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.38E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.94E-11 2.71E-09 Organic HAP Total 6.69E+01 1.71E-02 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.64E+03 1.35E-03 1.84E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF2

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.110 COAL HEAT INPUT (10^12 BTU/YR) = 41.82 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY06 ROUTINE ILB/FINES/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.693 DATE: 03/26/07 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.571 COAL H2O (AS-FIRED) % WT (AVG) 11.40 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW CY06 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 9.01 ILB/FINES/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,613 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 2.75 PM SO2 NOx MAX OF CY01-CY03 PM STACK TEST DATA(4) COAL FIRED TONS 1,800,390 0.11 1.2 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 17.7 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY WEIGHTED-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.94E+06 1.10E+05 94.35 2293 763 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.52E+05 7.46E+04 70.43 1559 519 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.07E+05 3.95E+04 63.00 825 275 NA NA Condensable PM (PM_cond) NA 2.00E+04 418 139 QA/QC: NA NA Sulfur dioxide (SO2) NA 4.49E+06 6.93E+05 84.58 15804 4820 0 36577 8351 Nitrogen oxides (NOx) NA 1.41E+06 5.71E+05 59.46 13040 3977 0 NA NA Carbon monoxide (CO) NA 2.15E+04 2.15E+04 0.00 450 150 Volatile organic compounds (VOC) NA 4.74E+03 4.74E+03 0.00 99.0 33.0 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.61E+05 5.14E+04 68.11 1075 358 Ammonia (NH3)(6) NA 4.36E+02 4.42E-02 99.99 9.23E-04 3.07E-04

PM Trace-Element HAP Antimony (Sb) 2.15E+00 1.64E+02 1.52E+00 99.07 3.18E-02 1.06E-02 Arsenic (As) 1.14E+01 8.68E+02 2.60E+01 97.00 5.43E-01 1.81E-01 Beryllium (Be) 2.00E+00 1.53E+02 2.87E+00 98.12 6.00E-02 2.00E-02 Cadmium (Cd) 6.66E-01 5.08E+01 2.50E+00 95.09 5.22E-02 1.74E-02 Chromium (Cr) 1.69E+01 1.29E+03 1.97E+01 98.47 4.12E-01 1.37E-01 Cobalt (Co) 3.92E+00 2.99E+02 4.53E+00 98.48 9.48E-02 3.16E-02 Lead (Pb) 1.42E+01 1.08E+03 3.04E+01 97.18 6.37E-01 2.12E-01 Manganese (Mn) 2.90E+01 2.22E+03 3.05E+01 98.62 6.37E-01 2.12E-01 Nickel (Ni) 1.98E+01 1.51E+03 1.90E+01 98.74 3.97E-01 1.32E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.59E+02 5.17E+04 1.55E+03 97.00 3.24E+01 1.08E+01 Hydrogen fluoride (HF) 9.15E+01 7.35E+03 4.41E+02 94.00 9.22E+00 3.07E+00 Mercury (Hg) 8.20E-02 6.26E+00 3.26E+00 47.96 6.81E-02 2.27E-02 Selenium (Se) 2.94E+00 2.25E+02 2.69E+01 88.03 5.62E-01 1.87E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 1.86E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 5.44E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.14E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.51E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.30E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 6.48E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.18E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 1.90E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 4.81E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.30E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 6.69E-02 2.23E-02 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.51E-02 8.35E-03 Acrolein (107028) NA 1.90E+00 0.00E+00 3.97E-02 1.32E-02 Benzene (71432) NA 3.90E+00 0.00E+00 8.15E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 5.85E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.35E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 7.53E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 1.86E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.30E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.35E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.11E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.67E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.30E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.21E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.30E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 1.88E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.67E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 5.44E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.02E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 8.57E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.18E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.51E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.28E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.30E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 7.53E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.30E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 6.90E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.14E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 3.97E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.46E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 8.78E-03 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 3.55E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 6.48E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.53E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.63E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.77E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 8.15E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.40E+00 4.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 2.64E+03 1.10E-01 1.84E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_preFGD_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 ILB COAL HEAT INPUT (10^12 BTU/YR) = 17.37 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 10.90 AIR POLLUTION CONTROL SYSTEM(S): ESPC ILB COAL ASH (AS-FIRED) % WT (AVG) 8.71 CY06 PRE-FGD FUEL & CY06 CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,756 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.78 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 738,759 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.85E+06 3.80E+04 97.95 330 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.41E+05 2.58E+04 89.27 224 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.02E+05 1.37E+04 86.57 119 157 NA NA Condensable PM (PM_cond) NA 2.48E+05 2154 2841 NA NA Sulfur dioxide (SO2) NA 4.49E+06 4.49E+06 0.00 39021 51477 270981 61868 Nitrogen oxides (NOx) NA 1.40E+06 2.97E+05 78.84 2917 3403 NA NA Carbon monoxide (CO) NA 2.13E+04 2.13E+04 0.00 185 244 Volatile organic compounds (VOC) NA 4.68E+03 4.68E+03 0.00 40.6 53.6 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.58E+05 1.03E+05 34.55 897 1184 Ammonia (NH3)(6) NA 6.30E+02 6.30E-01 99.90 5.48E-03 7.22E-03 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 2.00E+00 1.52E+02 7.85E-01 99.48 6.82E-03 8.99E-03 10.7 21.29 Arsenic (As) 1.10E+01 8.34E+02 1.07E+01 98.72 9.26E-02 1.22E-01 134 27.60 Beryllium (Be) 2.00E+00 1.52E+02 9.10E-01 99.40 7.90E-03 1.04E-02 10.4 34.16 Cadmium (Cd) 5.00E-01 3.79E+01 1.45E+00 96.16 1.26E-02 1.67E-02 20.9 17.30 Chromium (Cr) 1.60E+01 1.21E+03 1.07E+01 99.12 9.28E-02 1.22E-01 149 19.78 Cobalt (Co) 3.70E+00 2.80E+02 2.18E+00 99.22 1.90E-02 2.50E-02 29.2 23.06 Lead (Pb) 1.40E+01 1.06E+03 1.32E+01 98.76 1.15E-01 1.51E-01 169 26.21 Manganese (Mn) 2.90E+01 2.20E+03 1.63E+01 99.26 1.41E-01 1.86E-01 225 20.39 Nickel (Ni) 1.90E+01 1.44E+03 1.15E+01 99.20 9.98E-02 1.32E-01 166 16.67

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.76E+02 5.27E+04 5.27E+04 0.00 4.57E+02 6.03E+02 914,851 -0.01 Hydrogen fluoride (HF) 9.20E+01 7.34E+03 6.61E+03 10.00 5.74E+01 7.57E+01 114,781 0.005 Mercury (Hg) 8.00E-02 6.06E+00 4.71E+00 22.33 4.09E-02 5.40E-02 81.8 0.03 Selenium (Se) 1.70E+00 1.29E+02 7.09E+01 45.00 6.15E-01 8.12E-01 1,231 0.00001

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 7.73E-03 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 2.26E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 1.30E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 6.25E-03 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 9.55E-03 1.26E-02 2-Butanone (78933) NA 3.10E+00 2.69E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 1.74E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 7.90E-02 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 2.00E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 9.55E-03 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 2.78E-02 3.67E-02 55.6 0.001 Acetophenone (98862) NA 1.20E+00 1.04E-02 1.37E-02 20.8 0.001 Acrolein (107028) NA 1.90E+00 1.65E-02 2.18E-02 33.0 0.001 Benzene (71432) NA 3.90E+00 3.39E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 2.43E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 1.39E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 3.13E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 7.73E-03 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 9.55E-03 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 1.39E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 4.60E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 6.95E-03 9.17E-03 Chloromethane (74873) NA 1.10E+00 9.55E-03 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 5.04E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 9.55E-04 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 7.82E-04 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 6.95E-03 9.17E-03 Formaldehyde (50000) NA 2.60E+00 2.26E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 4.26E-03 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 3.56E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 1.74E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 1.04E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 5.30E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 9.55E-03 1.26E-02 Methylene chloride (75092) NA 3.60E+00 3.13E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 5.38E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 2.87E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 1.30E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 1.65E-02 2.18E-02 Styrene (100425) NA 7.00E-01 6.08E-03 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 3.65E-03 4.81E-03 Toluene (108883) NA 1.70E+00 1.48E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 2.69E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 6.34E-03 8.36E-03 Xylenes (1330207) NA 1.26E+00 1.09E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 1.15E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 3.39E-09 4.47E-09 Organic HAP Total 6.69E+01 5.81E-01 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 1.59E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_postFGD_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 ILB COAL HEAT INPUT (10^12 BTU/YR) = 13.64 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 10.90 AIR POLLUTION CONTROL SYSTEM(S): ESPC+FGDW ILB COAL ASH (AS-FIRED) % WT (AVG) 8.71 CY06 POST-FGD FUEL & CY06 CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,756 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.78 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 580,235 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 61.01 MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (post-FGD) = 0 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.85E+06 3.80E+04 97.95 259 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.41E+05 2.58E+04 89.27 176 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.02E+05 1.37E+04 86.57 93.3 157 NA NA Condensable PM (PM_cond) NA 2.00E+04 136 229 NA NA Sulfur dioxide (SO2) NA 4.49E+06 4.39E+05 90.23 2993 5027 270981 61868 Nitrogen oxides (NOx) NA 1.40E+06 2.97E+05 78.84 2291 3403 NA NA Carbon monoxide (CO) NA 2.13E+04 2.13E+04 0.00 145 244 Volatile organic compounds (VOC) NA 4.68E+03 4.68E+03 0.00 31.9 53.6 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.61E+05 4.97E+04 69.24 339 569 Ammonia (NH3)(6) 0 0 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 2.00E+00 1.52E+02 7.85E-01 99.48 5.36E-03 8.99E-03 8.4 21.29 Arsenic (As) 1.10E+01 8.34E+02 1.07E+01 98.72 7.27E-02 1.22E-01 105 27.60 Beryllium (Be) 2.00E+00 1.52E+02 9.10E-01 99.40 6.21E-03 1.04E-02 8.2 34.16 Cadmium (Cd) 5.00E-01 3.79E+01 1.45E+00 96.16 9.92E-03 1.67E-02 16.4 17.30 Chromium (Cr) 1.60E+01 1.21E+03 1.07E+01 99.12 7.29E-02 1.22E-01 117 19.78 Cobalt (Co) 3.70E+00 2.80E+02 2.18E+00 99.22 1.49E-02 2.50E-02 22.9 23.06 Lead (Pb) 1.40E+01 1.06E+03 1.32E+01 98.76 8.99E-02 1.51E-01 133 26.21 Manganese (Mn) 2.90E+01 2.20E+03 1.63E+01 99.26 1.11E-01 1.86E-01 177 20.39 Nickel (Ni) 1.90E+01 1.44E+03 1.15E+01 99.20 7.84E-02 1.32E-01 131 16.67

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.76E+02 5.27E+04 1.58E+03 97.00 1.08E+01 1.81E+01 21,556 -0.01 Hydrogen fluoride (HF) 9.20E+01 7.34E+03 4.41E+02 94.00 3.01E+00 5.05E+00 6,010 0.005 Mercury (Hg) 8.00E-02 6.06E+00 2.36E+00 61.01 1.61E-02 2.71E-02 32.2 0.02 Selenium (Se) 1.70E+00 1.29E+02 1.55E+01 88.00 1.05E-01 1.77E-01 211 -0.00003

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 6.07E-03 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 1.77E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 1.02E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 4.91E-03 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 7.50E-03 1.26E-02 2-Butanone (78933) NA 3.10E+00 2.11E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 1.36E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 6.21E-02 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 1.57E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 7.50E-03 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 2.18E-02 3.67E-02 43.7 0.001 Acetophenone (98862) NA 1.20E+00 8.19E-03 1.37E-02 16.4 0.001 Acrolein (107028) NA 1.90E+00 1.30E-02 2.18E-02 25.9 0.001 Benzene (71432) NA 3.90E+00 2.66E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 1.91E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 1.09E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 2.46E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 6.07E-03 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 7.50E-03 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 1.09E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 3.62E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 5.46E-03 9.17E-03 Chloromethane (74873) NA 1.10E+00 7.50E-03 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 3.96E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 7.50E-04 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 6.14E-04 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 5.46E-03 9.17E-03 Formaldehyde (50000) NA 2.60E+00 1.77E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 3.34E-03 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 2.80E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 1.36E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 8.19E-03 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 4.16E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 7.50E-03 1.26E-02 Methylene chloride (75092) NA 3.60E+00 2.46E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 4.23E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 2.25E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 1.02E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 1.30E-02 2.18E-02 Styrene (100425) NA 7.00E-01 4.77E-03 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 2.86E-03 4.81E-03 Toluene (108883) NA 1.70E+00 1.16E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 2.11E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 4.98E-03 8.36E-03 Xylenes (1330207) NA 1.26E+00 8.59E-03 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 9.04E-03 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 2.66E-09 4.47E-09 Organic HAP Total 6.69E+01 4.56E-01 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 1.25E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 COAL HEAT INPUT (10^12 BTU/YR) = 31.01 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: COAL H2O (AS-FIRED) % WT (AVG) 10.90 AIR POLLUTION CONTROL SYSTEM(S): ESPC COAL ASH (AS-FIRED) % WT (AVG) 8.71 CY06 FUEL & CEMS DATA(1) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,756 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) COAL SULFUR (AS-FIRED) % WT (AVG) 2.78 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) COAL FIRED TONS 1,318,994 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.85E+06 3.80E+04 97.95 589 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.41E+05 2.58E+04 89.27 401 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.02E+05 1.37E+04 86.57 212 157 NA NA Condensable PM (PM_cond) NA 1.48E+05 2290 1692 NA NA Sulfur dioxide (SO2) NA 4.49E+06 2.71E+06 39.69 42014 31043 270981 61868 Nitrogen oxides (NOx) NA 1.40E+06 2.97E+05 78.84 5208 3403 NA NA Carbon monoxide (CO) NA 2.13E+04 2.13E+04 0.00 330 244 Volatile organic compounds (VOC) NA 4.68E+03 4.68E+03 0.00 72.5 53.6 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.59E+05 7.97E+04 49.81 1236 913 Ammonia (NH3)(6) NA 3.53E+02 3.53E-01 99.90 5.48E-03 4.05E-03

PM Trace-Element HAP Antimony (Sb) 2.00E+00 1.52E+02 7.85E-01 99.48 1.22E-02 8.99E-03 Arsenic (As) 1.10E+01 8.34E+02 1.07E+01 98.72 1.65E-01 1.22E-01 Beryllium (Be) 2.00E+00 1.52E+02 9.10E-01 99.40 1.41E-02 1.04E-02 Cadmium (Cd) 5.00E-01 3.79E+01 1.45E+00 96.16 2.26E-02 1.67E-02 Chromium (Cr) 1.60E+01 1.21E+03 1.07E+01 99.12 1.66E-01 1.22E-01 Cobalt (Co) 3.70E+00 2.80E+02 2.18E+00 99.22 3.39E-02 2.50E-02 Lead (Pb) 1.40E+01 1.06E+03 1.32E+01 98.76 2.04E-01 1.51E-01 Manganese (Mn) 2.90E+01 2.20E+03 1.63E+01 99.26 2.52E-01 1.86E-01 Nickel (Ni) 1.90E+01 1.44E+03 1.15E+01 99.20 1.78E-01 1.32E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.76E+02 5.27E+04 3.02E+04 42.67 4.68E+02 3.46E+02 Hydrogen fluoride (HF) 9.20E+01 7.34E+03 3.90E+03 46.95 6.04E+01 4.46E+01 Mercury (Hg) 8.00E-02 6.06E+00 3.68E+00 39.34 5.70E-02 4.21E-02 Selenium (Se) 1.70E+00 1.29E+02 4.65E+01 63.92 7.21E-01 5.33E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.38E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 4.03E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 2.33E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.12E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 1.71E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 4.81E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 3.10E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 1.41E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 3.57E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 1.71E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 4.96E-02 3.67E-02 Acetophenone (98862) NA 1.20E+00 1.86E-02 1.37E-02 Acrolein (107028) NA 1.90E+00 2.95E-02 2.18E-02 Benzene (71432) NA 3.90E+00 6.05E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 4.34E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 2.48E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 5.58E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 1.38E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 1.71E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 2.48E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 8.22E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 1.24E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 1.71E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 8.99E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 1.71E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 1.40E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.24E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 4.03E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 7.60E-03 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 6.36E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 3.10E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 1.86E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 9.46E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 1.71E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 5.58E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 9.61E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 5.12E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 2.33E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 2.95E-02 2.18E-02 Styrene (100425) NA 7.00E-01 1.09E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 6.51E-03 4.81E-03 Toluene (108883) NA 1.70E+00 2.64E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 4.81E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.13E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 1.95E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.05E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 6.05E-09 4.47E-09 Organic HAP Total 6.69E+01 1.04E+00 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 2.84E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_preFGD_ILB_fines

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 ILB COAL HEAT INPUT (10^12 BTU/YR) = 0.39 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) FINES SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: ILB COAL FINES H2O (AS-FIRED) % WT (AVG) 24.00 AIR POLLUTION CONTROL SYSTEM(S): ESPC ILB COAL FINES ASH (AS-FIRED) % WT (AVG) 27.40 CY06 PRE-FGD FUEL & CY06 CEMS DATA(1) ILB FINES HEAT VALUE (AS-FIRED) BTU/LB (AVG) 6,673 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB FINES TRACE-ELEMENT CONCENTRATNS(2) ILB COAL FINES SULFUR (AS-FIRED)% WT (AVG) 3.06 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FINES FIRED (AS-FIRED) TONS 29,054 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY AVERAGE ILB FINESUNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.03E+07 3.80E+04 99.63 7.37 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.33E+06 2.58E+04 98.06 5.01 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 5.65E+05 1.37E+04 97.58 2.65 157 NA NA Condensable PM (PM_cond) NA 2.76E+05 53.5 3162 NA NA Sulfur dioxide (SO2) NA 8.71E+06 8.71E+06 0.00 1689 99822 270981 61868 Nitrogen oxides (NOx) NA 2.47E+06 2.97E+05 87.99 115 3403 NA NA Carbon monoxide (CO) NA 3.75E+04 3.75E+04 0.00 7.26 429 Comparison w/ 3-2-07 LT Outputs: Volatile organic compounds (VOC) NA 8.24E+03 8.24E+03 0.00 1.60 94.4 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 3.10E+05 2.03E+05 34.55 39.3 2321 100.0 Ammonia (NH3)(6) NA 6.30E+02 6.19E-01 99.90 1.20E-04 7.09E-03

PM Trace-Element HAP Antimony (Sb) 1.25E+01 1.42E+03 1.09E+00 99.92 2.12E-04 1.25E-02 100.000 Arsenic (As) 4.18E+01 4.76E+03 1.09E+01 99.77 2.12E-03 1.25E-01 100.000 Beryllium (Be) 3.50E+00 3.99E+02 4.01E-01 99.90 7.77E-05 4.59E-03 100.0000 Cadmium (Cd) 1.10E+01 1.25E+03 3.55E+00 99.72 6.89E-04 4.07E-02 100.000 Chromium (Cr) 7.98E+01 9.09E+03 1.27E+01 99.86 2.47E-03 1.46E-01 100.0000 Cobalt (Co) 1.90E+01 2.16E+03 2.75E+00 99.87 5.32E-04 3.15E-02 100.000 Lead (Pb) 3.20E+01 3.64E+03 8.99E+00 99.75 1.74E-03 1.03E-01 100.000 Manganese (Mn) 4.40E+01 5.01E+03 9.54E+00 99.81 1.85E-03 1.09E-01 100.0000 Nickel (Ni) 8.05E+01 9.17E+03 1.23E+01 99.87 2.38E-03 1.41E-01 100.000

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 1.58E+02 1.85E+04 1.85E+04 0.00 3.59E+00 2.12E+02 100.00 Hydrogen fluoride (HF) 9.20E+01 1.10E+04 9.93E+03 10.00 1.93E+00 1.14E+02 100.000 Mercury (Hg) 2.21E-01 2.52E+01 2.52E+01 0.00 4.88E-03 2.88E-01 100.00 Selenium (Se) 7.88E+01 8.97E+03 4.94E+03 45.00 9.57E-01 5.66E+01 100.000

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.73E-04 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 5.04E-04 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 2.91E-04 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.40E-04 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.13E-04 1.26E-02 2-Butanone (78933) NA 3.10E+00 6.01E-04 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 3.88E-05 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 1.76E-03 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 4.46E-04 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 2.13E-04 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 6.20E-04 3.67E-02 100.0000 Acetophenone (98862) NA 1.20E+00 2.33E-04 1.37E-02 100.0000 Acrolein (107028) NA 1.90E+00 3.68E-04 2.18E-02 100.0000 Benzene (71432) NA 3.90E+00 7.56E-04 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 5.43E-05 3.21E-03 Biphenyl (92524) NA 1.60E-01 3.10E-05 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 6.98E-04 4.12E-02 Bromomethane (74839) NA 8.90E-01 1.73E-04 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 2.13E-04 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 3.10E-05 1.83E-03 Chloroethane (75003) NA 5.30E-01 1.03E-04 6.07E-03 Chloroform (67663) NA 8.00E-01 1.55E-04 9.17E-03 Chloromethane (74873) NA 1.10E+00 2.13E-04 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 1.12E-04 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 2.13E-05 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 1.74E-05 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.55E-04 9.17E-03 Formaldehyde (50000) NA 2.60E+00 5.04E-04 2.98E-02 n-Hexane (110543) NA 4.90E-01 9.50E-05 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 7.95E-07 4.70E-05 Iodomethane (74884) NA 2.00E+00 3.88E-04 2.29E-02 Isophorone (78591) NA 1.20E+00 2.33E-04 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 1.18E-04 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 2.13E-04 1.26E-02 Methylene chloride (75092) NA 3.60E+00 6.98E-04 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.20E-04 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 6.40E-04 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 2.91E-06 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 3.68E-04 2.18E-02 Styrene (100425) NA 7.00E-01 1.36E-04 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 8.14E-05 4.81E-03 Toluene (108883) NA 1.70E+00 3.30E-04 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 6.01E-05 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.42E-04 8.36E-03 Xylenes (1330207) NA 1.26E+00 2.44E-04 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.57E-04 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 7.56E-11 4.47E-09 Organic HAP Total 6.69E+01 1.30E-02 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 3.55E-04 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_postFGD_ILB_fines

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 ILB COAL HEAT INPUT (10^12 BTU/YR) = 0.42 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) FINES SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: ILB COAL FINES H2O (AS-FIRED) % WT (AVG) 24.00 AIR POLLUTION CONTROL SYSTEM(S): ESPC+FGDW ILB COAL FINES ASH (AS-FIRED) % WT (AVG) 27.40 CY06 POST-FGD FUEL & CY06 CEMS DATA(1) ILB FINES HEAT VALUE (AS-FIRED) BTU/LB (AVG) 6,673 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB FINES TRACE-ELEMENT CONCENTRATNS(2) ILB COAL FINES SULFUR (AS-FIRED)% WT (AVG) 3.06 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FINES FIRED (AS-FIRED) TONS 31,188 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0
Hg Contrl Efficiency (%) w/in-service SCR = 86 MEDIAN EFH HOURLY Hg Contrl Efficiency (%) w/o in-service SCR = 44.19 AVERAGE ILB FINESUNCONTROLLED CONTROLLED ESTIMATED EMISSIONSSCR operation factor (post-FGD) = 0 TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.03E+07 3.80E+04 99.63 7.91 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.33E+06 2.58E+04 98.06 5.38 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 5.65E+05 1.37E+04 97.58 2.85 157 NA NA Condensable PM (PM_cond) NA 2.00E+04 4.16 229 NA NA Sulfur dioxide (SO2) NA 8.71E+06 8.51E+05 90.23 177 9748 270981 61868 Nitrogen oxides (NOx) NA 2.47E+06 2.97E+05 87.99 123 3403 NA NA Carbon monoxide (CO) NA 3.75E+04 3.75E+04 0.00 7.80 429 Comparison w/ 3-2-07 LT Outputs: Volatile organic compounds (VOC) NA 8.24E+03 8.24E+03 0.00 1.72 94.4 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 3.13E+05 9.63E+04 69.24 20.0 1104 100.0 Ammonia (NH3)(6) 0 0

PM Trace-Element HAP Antimony (Sb) 1.25E+01 1.42E+03 1.09E+00 99.92 2.28E-04 1.25E-02 100.000 Arsenic (As) 4.18E+01 4.76E+03 1.09E+01 99.77 2.28E-03 1.25E-01 100.000 Beryllium (Be) 3.50E+00 3.99E+02 4.01E-01 99.90 8.34E-05 4.59E-03 100.0000 Cadmium (Cd) 1.10E+01 1.25E+03 3.55E+00 99.72 7.40E-04 4.07E-02 100.000 Chromium (Cr) 7.98E+01 9.09E+03 1.27E+01 99.86 2.65E-03 1.46E-01 100.0000 Cobalt (Co) 1.90E+01 2.16E+03 2.75E+00 99.87 5.71E-04 3.15E-02 100.000 Lead (Pb) 3.20E+01 3.64E+03 8.99E+00 99.75 1.87E-03 1.03E-01 100.000 Manganese (Mn) 4.40E+01 5.01E+03 9.54E+00 99.81 1.99E-03 1.09E-01 100.0000 Nickel (Ni) 8.05E+01 9.17E+03 1.23E+01 99.87 2.56E-03 1.41E-01 100.000

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 1.58E+02 1.85E+04 5.55E+02 97.00 1.16E-01 6.36E+00 100.00 Hydrogen fluoride (HF) 9.20E+01 1.10E+04 6.62E+02 94.00 1.38E-01 7.58E+00 100.000 Mercury (Hg) 2.21E-01 2.52E+01 1.40E+01 44.19 2.92E-03 1.61E-01 100.00 Selenium (Se) 7.88E+01 8.97E+03 1.08E+03 88.00 2.24E-01 1.23E+01 100.000

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.85E-04 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 5.41E-04 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.12E-04 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.50E-04 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.29E-04 1.26E-02 2-Butanone (78933) NA 3.10E+00 6.45E-04 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.16E-05 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 1.89E-03 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 4.79E-04 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 2.29E-04 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 6.66E-04 3.67E-02 100.0000 Acetophenone (98862) NA 1.20E+00 2.50E-04 1.37E-02 100.0000 Acrolein (107028) NA 1.90E+00 3.95E-04 2.18E-02 100.0000 Benzene (71432) NA 3.90E+00 8.12E-04 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 5.83E-05 3.21E-03 Biphenyl (92524) NA 1.60E-01 3.33E-05 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 7.49E-04 4.12E-02 Bromomethane (74839) NA 8.90E-01 1.85E-04 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 2.29E-04 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 3.33E-05 1.83E-03 Chloroethane (75003) NA 5.30E-01 1.10E-04 6.07E-03 Chloroform (67663) NA 8.00E-01 1.66E-04 9.17E-03 Chloromethane (74873) NA 1.10E+00 2.29E-04 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 1.21E-04 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 2.29E-05 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 1.87E-05 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.66E-04 9.17E-03 Formaldehyde (50000) NA 2.60E+00 5.41E-04 2.98E-02 n-Hexane (110543) NA 4.90E-01 1.02E-04 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 8.53E-07 4.70E-05 Iodomethane (74884) NA 2.00E+00 4.16E-04 2.29E-02 Isophorone (78591) NA 1.20E+00 2.50E-04 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 1.27E-04 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 2.29E-04 1.26E-02 Methylene chloride (75092) NA 3.60E+00 7.49E-04 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.29E-04 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 6.87E-04 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.12E-06 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 3.95E-04 2.18E-02 Styrene (100425) NA 7.00E-01 1.46E-04 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 8.74E-05 4.81E-03 Toluene (108883) NA 1.70E+00 3.54E-04 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 6.45E-05 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.52E-04 8.36E-03 Xylenes (1330207) NA 1.26E+00 2.62E-04 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.76E-04 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 8.12E-11 4.47E-09 Organic HAP Total 6.69E+01 1.39E-02 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 3.81E-04 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_ILB_fines

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 COAL HEAT INPUT (10^12 BTU/YR) = 0.80 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILLINOIS-BASIN (ILB) FINES SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: COAL H2O (AS-FIRED) % WT (AVG) 24.00 AIR POLLUTION CONTROL SYSTEM(S): ESPC COAL ASH (AS-FIRED) % WT (AVG) 27.40 CY06 FUEL & CEMS DATA(1) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 6,673 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB FINES TRACE-ELEMENT CONCENTRATNS(2) COAL SULFUR (AS-FIRED) % WT (AVG) 3.06 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) COAL FIRED TONS 60,242 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY AVERAGE ILB FINESUNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.03E+07 3.80E+04 99.63 15.3 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.33E+06 2.58E+04 98.06 10.4 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 5.65E+05 1.37E+04 97.58 5.50 157 NA NA Condensable PM (PM_cond) NA 1.43E+05 57.7 1644 NA NA Sulfur dioxide (SO2) NA 8.71E+06 4.64E+06 46.72 1866 53189 270981 61868 Nitrogen oxides (NOx) NA 2.47E+06 2.97E+05 87.99 238 3403 NA NA Carbon monoxide (CO) NA 3.75E+04 3.75E+04 0.00 15.1 429 Volatile organic compounds (VOC) NA 8.24E+03 8.24E+03 0.00 3.31 94.4 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 3.11E+05 1.48E+05 52.51 59.3 1691 Ammonia (NH3)(6) NA 3.04E+02 2.99E-01 99.90 1.20E-04 3.42E-03

PM Trace-Element HAP Antimony (Sb) 1.25E+01 1.42E+03 1.09E+00 99.92 4.40E-04 1.25E-02 Arsenic (As) 4.18E+01 4.76E+03 1.09E+01 99.77 4.40E-03 1.25E-01 Beryllium (Be) 3.50E+00 3.99E+02 4.01E-01 99.90 1.61E-04 4.59E-03 Cadmium (Cd) 1.10E+01 1.25E+03 3.55E+00 99.72 1.43E-03 4.07E-02 Chromium (Cr) 7.98E+01 9.09E+03 1.27E+01 99.86 5.11E-03 1.46E-01 Cobalt (Co) 1.90E+01 2.16E+03 2.75E+00 99.87 1.10E-03 3.15E-02 Lead (Pb) 3.20E+01 3.64E+03 8.99E+00 99.75 3.61E-03 1.03E-01 Manganese (Mn) 4.40E+01 5.01E+03 9.54E+00 99.81 3.84E-03 1.09E-01 Nickel (Ni) 8.05E+01 9.17E+03 1.23E+01 99.87 4.94E-03 1.41E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 1.58E+02 1.85E+04 9.21E+03 50.22 3.70E+00 1.06E+02 Hydrogen fluoride (HF) 9.20E+01 1.10E+04 5.13E+03 53.49 2.06E+00 5.88E+01 Mercury (Hg) 2.21E-01 2.52E+01 1.94E+01 22.88 7.80E-03 2.22E-01 Selenium (Se) 7.88E+01 8.97E+03 2.94E+03 67.26 1.18E+00 3.37E+01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 3.58E-04 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 1.05E-03 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 6.03E-04 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 2.89E-04 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 4.42E-04 1.26E-02 2-Butanone (78933) NA 3.10E+00 1.25E-03 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 8.04E-05 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 3.66E-03 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 9.25E-04 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 4.42E-04 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 1.29E-03 3.67E-02 Acetophenone (98862) NA 1.20E+00 4.82E-04 1.37E-02 Acrolein (107028) NA 1.90E+00 7.64E-04 2.18E-02 Benzene (71432) NA 3.90E+00 1.57E-03 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 1.13E-04 3.21E-03 Biphenyl (92524) NA 1.60E-01 6.43E-05 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 1.45E-03 4.12E-02 Bromomethane (74839) NA 8.90E-01 3.58E-04 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 4.42E-04 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 6.43E-05 1.83E-03 Chloroethane (75003) NA 5.30E-01 2.13E-04 6.07E-03 Chloroform (67663) NA 8.00E-01 3.22E-04 9.17E-03 Chloromethane (74873) NA 1.10E+00 4.42E-04 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 2.33E-04 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 4.42E-05 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 3.62E-05 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 3.22E-04 9.17E-03 Formaldehyde (50000) NA 2.60E+00 1.05E-03 2.98E-02 n-Hexane (110543) NA 4.90E-01 1.97E-04 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.65E-06 4.70E-05 Iodomethane (74884) NA 2.00E+00 8.04E-04 2.29E-02 Isophorone (78591) NA 1.20E+00 4.82E-04 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 2.45E-04 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 4.42E-04 1.26E-02 Methylene chloride (75092) NA 3.60E+00 1.45E-03 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 2.49E-04 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 1.33E-03 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 6.03E-06 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 7.64E-04 2.18E-02 Styrene (100425) NA 7.00E-01 2.81E-04 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.69E-04 4.81E-03 Toluene (108883) NA 1.70E+00 6.83E-04 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 1.25E-04 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 2.93E-04 8.36E-03 Xylenes (1330207) NA 1.26E+00 5.07E-04 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 5.33E-04 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 1.57E-10 4.47E-09 Organic HAP Total 6.69E+01 2.69E-02 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 7.36E-04 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 PRB COAL HEAT INPUT (10^12 BTU/YR) = 31.71 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 26.70 AIR POLLUTION CONTROL SYSTEM(S): ESPC PRB COAL ASH (AS-FIRED) % WT (AVG) 5.42 CY06 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,851 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.29 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 1,791,422 0.11 5.4 NA MAX OF CY01-CY03 PM STACK TEST DATA(4) ASH SPLIT TO BOTTOM % 75 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY MEDIAN PRB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.53E+06 3.80E+04 97.52 603 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.99E+05 2.58E+04 87.02 410 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.42E+04 1.37E+04 83.75 217 157 NA NA Condensable PM (PM_cond) NA 1.00E+04 159 115 NA NA Sulfur dioxide (SO2) NA 5.73E+05 5.73E+05 0.00 9091 6569 270981 61868 Nitrogen oxides (NOx) NA 9.60E+05 2.97E+05 69.07 3644 3403 NA NA Carbon monoxide (CO) NA 2.82E+04 2.82E+04 0.00 448 324 Volatile organic compounds (VOC) NA 6.21E+03 6.21E+03 0.00 98.5 71.2 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA -9.35E+02 -3.82E+02 59.12 -6.06 -4.38 Ammonia (NH3)(6) NA 6.30E+02 4.73E+02 25.00 7.49 5.42 Comparison w/ 3-2-07 LT Outputs:

PM Trace-Element HAP Air rel, lb/yr % Difference Antimony (Sb) 1.50E-01 1.24E+01 1.83E-01 98.53 2.90E-03 2.10E-03 4.57 21.24 Arsenic (As) 1.20E+00 9.94E+01 2.06E+00 97.93 3.26E-02 2.36E-02 47.2 27.54 Beryllium (Be) 2.50E-01 2.07E+01 1.26E-01 99.39 1.99E-03 1.44E-03 2.62 34.09 Cadmium (Cd) 1.10E-01 9.11E+00 7.85E-01 91.39 1.24E-02 8.99E-03 20.6 17.26 Chromium (Cr) 4.30E+00 3.56E+02 5.86E+00 98.35 9.29E-02 6.71E-02 149 19.73 Cobalt (Co) 1.60E+00 1.33E+02 1.49E+00 98.88 2.36E-02 1.70E-02 36.3 23.01 Lead (Pb) 3.20E+00 2.65E+02 5.06E+00 98.09 8.03E-02 5.80E-02 119 26.15 Manganese (Mn) 1.40E+01 1.16E+03 1.24E+01 98.93 1.97E-01 1.42E-01 314 20.34 Nickel (Ni) 2.90E+00 2.40E+02 5.33E+00 97.78 8.45E-02 6.11E-02 141 16.63

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.82E+01 5.81E+03 1.16E+03 80.00 1.84E+01 1.33E+01 36,825 0.06 Hydrogen fluoride (HF) 5.20E+01 4.53E+03 2.27E+03 50.00 3.60E+01 2.60E+01 71,901 0.005 Mercury (Hg) 6.00E-02 4.97E+00 4.05E+00 18.43 6.43E-02 4.64E-02 129 0.002 Selenium (Se) 7.40E-01 6.13E+01 1.84E+00 97.00 2.92E-02 2.11E-02 58.3 -0.00002

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.41E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 4.12E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 2.38E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.14E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 1.74E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 4.92E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 3.17E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 1.44E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 3.65E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 1.74E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 5.07E-02 3.67E-02 100.000 Acetophenone (98862) NA 1.20E+00 1.90E-02 1.37E-02 100.000 Acrolein (107028) NA 1.90E+00 3.01E-02 2.18E-02 100.000 Benzene (71432) NA 3.90E+00 6.18E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 4.44E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 2.54E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 5.71E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 1.41E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 1.74E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 2.54E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 8.40E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 1.27E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 1.74E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 9.20E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 1.74E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 1.43E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.27E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 4.12E-02 2.98E-02 100.000 n-Hexane (110543) NA 4.90E-01 7.77E-03 5.61E-03 100.000 Hexachlorobenzene (118741) NA 4.10E-03 6.50E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 3.17E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 1.90E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 9.67E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 1.74E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 5.71E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 9.83E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 5.23E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 2.38E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 3.01E-02 2.18E-02 Styrene (100425) NA 7.00E-01 1.11E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 6.66E-03 4.81E-03 Toluene (108883) NA 1.70E+00 2.70E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 4.92E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.16E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 2.00E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.10E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 6.18E-09 4.47E-09 Organic HAP Total 6.69E+01 1.06E+00 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 2.90E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_preFGD

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 COAL HEAT INPUT (10^12 BTU/YR) = 49.47 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILB/FINES/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 COAL H2O (AS-FIRED) % WT (AVG) 22.11 AIR POLLUTION CONTROL SYSTEM(S): ESPC CY06 PRE-FGD FUEL & CY06 CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 6.62 ILB/FINES/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 9,665 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 1.04 PM SO2 NOx MAX OF CY01-CY03 PM STACK TEST DATA(4) COAL FIRED TONS 2,559,235 0.11 5.4 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 13.0 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY WEIGHTED-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.71E+06 3.80E+04 97.78 940 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.23E+05 2.58E+04 88.39 639 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 9.42E+04 1.37E+04 85.47 338 157 NA NA Condensable PM (PM_cond) NA 9.57E+04 2366 1096 NA NA Sulfur dioxide (SO2) NA 2.01E+06 2.01E+06 0.00 49802 23068 270981 61868 Nitrogen oxides (NOx) NA 1.13E+06 2.97E+05 73.66 6675 3403 NA NA Carbon monoxide (CO) NA 2.59E+04 2.59E+04 0.00 640 296 Volatile organic compounds (VOC) NA 5.69E+03 5.69E+03 0.00 141 65.2 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 6.09E+04 3.76E+04 38.21 930 431 Ammonia (NH3)(6) NA 6.30E+02 3.03E+02 51.89 7.50 3.47

PM Trace-Element HAP Antimony (Sb) 8.98E-01 7.23E+01 4.02E-01 99.44 9.93E-03 4.60E-03 Arsenic (As) 4.89E+00 3.94E+02 5.15E+00 98.69 1.27E-01 5.90E-02 Beryllium (Be) 8.64E-01 6.96E+01 4.03E-01 99.42 9.97E-03 4.62E-03 Cadmium (Cd) 3.59E-01 2.90E+01 1.04E+00 96.40 2.58E-02 1.19E-02 Chromium (Cr) 9.00E+00 7.25E+02 7.61E+00 98.95 1.88E-01 8.71E-02 Cobalt (Co) 2.49E+00 2.00E+02 1.74E+00 99.13 4.31E-02 1.99E-02 Lead (Pb) 7.09E+00 5.71E+02 7.95E+00 98.61 1.97E-01 9.10E-02 Manganese (Mn) 1.93E+01 1.55E+03 1.37E+01 99.12 3.40E-01 1.57E-01 Nickel (Ni) 9.08E+00 7.31E+02 7.55E+00 98.97 1.87E-01 8.65E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 2.70E+02 2.24E+04 1.94E+04 13.32 4.79E+02 2.22E+02 Hydrogen fluoride (HF) 6.57E+01 5.57E+03 3.85E+03 30.87 9.53E+01 4.41E+01 Mercury (Hg) 6.84E-02 5.51E+00 4.45E+00 19.27 1.10E-01 5.10E-02 Selenium (Se) 1.92E+00 1.55E+02 6.48E+01 58.19 1.60E+00 7.42E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.20E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 6.43E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.71E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.78E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.72E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 7.67E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.95E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 2.25E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.69E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 2.72E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 7.92E-02 3.67E-02 Acetophenone (98862) NA 1.20E+00 2.97E-02 1.37E-02 Acrolein (107028) NA 1.90E+00 4.70E-02 2.18E-02 Benzene (71432) NA 3.90E+00 9.65E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 6.93E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 3.96E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 8.90E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 2.20E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 2.72E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 3.96E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 1.31E-02 6.07E-03 Chloroform (67663) NA 8.00E-01 1.98E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 2.72E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 1.43E-02 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 2.72E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 2.23E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.98E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 6.43E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 1.21E-02 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.01E-04 4.70E-05 Iodomethane (74884) NA 2.00E+00 4.95E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 2.97E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 1.51E-02 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 2.72E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 8.90E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.53E-02 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 8.16E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.71E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 4.70E-02 2.18E-02 Styrene (100425) NA 7.00E-01 1.73E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.04E-02 4.81E-03 Toluene (108883) NA 1.70E+00 4.20E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 7.67E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.81E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 3.12E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.28E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.65E-09 4.47E-09 Organic HAP Total 6.69E+01 1.65E+00 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 4.53E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3_postFGD

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 COAL HEAT INPUT (10^12 BTU/YR) = 14.06 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILB/FINES/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 COAL H2O (AS-FIRED) % WT (AVG) 11.57 AIR POLLUTION CONTROL SYSTEM(S): ESPC+FGDW CY06 POST-FGD FUEL & CY06 CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 9.66 ILB/FINES/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,497 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 2.79 PM SO2 NOx MAX OF CY01-CY03 PM STACK TEST DATA(4) COAL FIRED TONS 611,423 0.11 5.4 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 17.6 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY WEIGHTED-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 2.10E+06 3.80E+04 98.19 267 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.73E+05 2.58E+04 90.54 182 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.16E+05 1.37E+04 88.16 96.2 157 NA NA Condensable PM (PM_cond) NA 2.00E+04 141 229 NA NA Sulfur dioxide (SO2) NA 4.62E+06 4.51E+05 90.23 3170 5167 270981 61868 Nitrogen oxides (NOx) NA 1.44E+06 2.97E+05 79.30 2414 3403 NA NA Carbon monoxide (CO) NA 2.17E+04 2.17E+04 0.00 153 249 Volatile organic compounds (VOC) NA 4.78E+03 4.78E+03 0.00 33.6 54.8 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.66E+05 5.11E+04 69.24 359 585 Ammonia (NH3)(6) 0 0

PM Trace-Element HAP Antimony (Sb) 2.46E+00 1.89E+02 7.94E-01 99.58 5.58E-03 9.10E-03 Arsenic (As) 1.24E+01 9.50E+02 1.07E+01 98.88 7.50E-02 1.22E-01 Beryllium (Be) 2.07E+00 1.59E+02 8.95E-01 99.44 6.29E-03 1.03E-02 Cadmium (Cd) 9.60E-01 7.39E+01 1.52E+00 97.95 1.07E-02 1.74E-02 Chromium (Cr) 1.88E+01 1.45E+03 1.07E+01 99.26 7.55E-02 1.23E-01 Cobalt (Co) 4.37E+00 3.36E+02 2.20E+00 99.35 1.55E-02 2.52E-02 Lead (Pb) 1.48E+01 1.14E+03 1.31E+01 98.85 9.18E-02 1.50E-01 Manganese (Mn) 2.97E+01 2.28E+03 1.61E+01 99.30 1.13E-01 1.84E-01 Nickel (Ni) 2.17E+01 1.67E+03 1.15E+01 99.31 8.09E-02 1.32E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.53E+02 5.17E+04 1.55E+03 97.00 1.09E+01 1.78E+01 Hydrogen fluoride (HF) 9.20E+01 7.45E+03 4.47E+02 94.00 3.14E+00 5.12E+00 Mercury (Hg) 8.62E-02 6.63E+00 2.71E+00 59.12 1.91E-02 3.11E-02 Selenium (Se) 5.08E+00 3.91E+02 4.69E+01 88.00 3.30E-01 5.37E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 6.26E-03 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 1.83E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 1.05E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 5.06E-03 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 7.73E-03 1.26E-02 2-Butanone (78933) NA 3.10E+00 2.18E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 1.41E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 6.40E-02 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 1.62E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 7.73E-03 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 2.25E-02 3.67E-02 Acetophenone (98862) NA 1.20E+00 8.44E-03 1.37E-02 Acrolein (107028) NA 1.90E+00 1.34E-02 2.18E-02 Benzene (71432) NA 3.90E+00 2.74E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 1.97E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 1.12E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 2.53E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 6.26E-03 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 7.73E-03 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 1.12E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 3.73E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 5.62E-03 9.17E-03 Chloromethane (74873) NA 1.10E+00 7.73E-03 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 4.08E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 7.73E-04 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 6.33E-04 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 5.62E-03 9.17E-03 Formaldehyde (50000) NA 2.60E+00 1.83E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 3.44E-03 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 2.88E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 1.41E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 8.44E-03 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 4.29E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 7.73E-03 1.26E-02 Methylene chloride (75092) NA 3.60E+00 2.53E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 4.36E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 2.32E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 1.05E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 1.34E-02 2.18E-02 Styrene (100425) NA 7.00E-01 4.92E-03 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 2.95E-03 4.81E-03 Toluene (108883) NA 1.70E+00 1.19E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 2.18E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 5.13E-03 8.36E-03 Xylenes (1330207) NA 1.26E+00 8.86E-03 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 9.31E-03 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 2.74E-09 4.47E-09 Organic HAP Total 6.69E+01 4.70E-01 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 1.29E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1PAF3

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.038 COAL HEAT INPUT (10^12 BTU/YR) = 63.53 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY06 ROUTINE ILB/FINES/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 1.73 DATE: 03/26/07 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.297 COAL H2O (AS-FIRED) % WT (AVG) 20.08 AIR POLLUTION CONTROL SYSTEM(S): ESPC CY06 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 7.21 ILB/FINES/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 10,018 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 1.38 PM SO2 NOx MAX OF CY01-CY03 PM STACK TEST DATA(4) COAL FIRED TONS 3,170,658 0.11 5.4 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 14.0 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY WEIGHTED-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS TRACE-ELEMENT COAL EMISSION COAL EMISSION EFH CONTROL ANNUAL AT RATED Pollutant/Category CONCENTRATION FACTOR FACTOR EFFICIENCY EMISSIONS CAPACITY MAX ALLOWABLE EMISSIONS

MG/KG (DRY)(2) LB/10^12 BTU LB/10^12 BTU % TONS/YR LB/HR TONS/YR LB/HR Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) NA 1.80E+06 3.80E+04 97.89 1207 435 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.34E+05 2.58E+04 88.95 821 296 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 9.89E+04 1.37E+04 86.17 435 157 NA NA Condensable PM (PM_cond) NA 7.89E+04 2506 904 QA/QC: NA NA Sulfur dioxide (SO2) NA 2.59E+06 1.73E+06 33.16 52972 19832 0 270981 61868 Nitrogen oxides (NOx) NA 1.20E+06 2.97E+05 75.16 9090 3403 0 NA NA Carbon monoxide (CO) NA 2.50E+04 2.50E+04 0.00 793 286 Volatile organic compounds (VOC) NA 5.49E+03 5.49E+03 0.00 174 62.9 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 8.41E+04 4.06E+04 51.76 1289 465 Ammonia (NH3)(6) NA 4.91E+02 2.36E+02 51.89 7.50 2.71

PM Trace-Element HAP Antimony (Sb) 1.23E+00 9.82E+01 4.88E-01 99.50 1.55E-02 5.60E-03 Arsenic (As) 6.48E+00 5.17E+02 6.37E+00 98.77 2.02E-01 7.30E-02 Beryllium (Be) 1.12E+00 8.94E+01 5.12E-01 99.43 1.63E-02 5.86E-03 Cadmium (Cd) 4.88E-01 3.89E+01 1.15E+00 97.05 3.64E-02 1.31E-02 Chromium (Cr) 1.11E+01 8.85E+02 8.30E+00 99.06 2.64E-01 9.51E-02 Cobalt (Co) 2.89E+00 2.30E+02 1.84E+00 99.20 5.85E-02 2.11E-02 Lead (Pb) 8.73E+00 6.96E+02 9.08E+00 98.70 2.88E-01 1.04E-01 Manganese (Mn) 2.15E+01 1.72E+03 1.43E+01 99.17 4.53E-01 1.63E-01 Nickel (Ni) 1.18E+01 9.39E+02 8.42E+00 99.10 2.68E-01 9.65E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 3.52E+02 2.88E+04 1.54E+04 46.49 4.90E+02 1.77E+02 Hydrogen fluoride (HF) 7.13E+01 5.99E+03 3.10E+03 48.26 9.84E+01 3.55E+01 Mercury (Hg) 7.22E-02 5.76E+00 4.06E+00 29.42 1.29E-01 4.66E-02 Selenium (Se) 2.60E+00 2.07E+02 6.08E+01 70.64 1.93E+00 6.97E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.83E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 8.26E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 4.76E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 2.29E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 3.49E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 9.85E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 6.35E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 2.89E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 7.31E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 3.49E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 1.02E-01 3.67E-02 Acetophenone (98862) NA 1.20E+00 3.81E-02 1.37E-02 Acrolein (107028) NA 1.90E+00 6.04E-02 2.18E-02 Benzene (71432) NA 3.90E+00 1.24E-01 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 8.89E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 5.08E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 1.14E-01 4.12E-02 Bromomethane (74839) NA 8.90E-01 2.83E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 3.49E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 5.08E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 1.68E-02 6.07E-03 Chloroform (67663) NA 8.00E-01 2.54E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 3.49E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 1.84E-02 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 3.49E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 2.86E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 2.54E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 8.26E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 1.56E-02 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.30E-04 4.70E-05 Iodomethane (74884) NA 2.00E+00 6.35E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 3.81E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 1.94E-02 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 3.49E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 1.14E-01 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.97E-02 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 1.05E-01 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 4.76E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 6.04E-02 2.18E-02 Styrene (100425) NA 7.00E-01 2.22E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.33E-02 4.81E-03 Toluene (108883) NA 1.70E+00 5.40E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 9.85E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 2.32E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 4.00E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 4.21E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 1.24E-08 4.47E-09 Organic HAP Total 6.69E+01 2.12E+00 7.66E-01
pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 9.15E+02 5.81E-02 1.05E-05

Notes:
(1) CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(2) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.
(3) Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil).
(4) Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(5) "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(6) Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR INSIGNIF. BREAKER NO. 1 & 2 DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 4.00 6.76 LB/VMT 100T/HR 2.70E-01 5.41E+01 NONE 0 2.70E-01 5.41E+01 EMISSION REFUSE DISPOSAL REFUSE HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1000T/YR SOURCE ACTIVITIES ONE-WAY FULL (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 81 25T/TRIP NO. OF WHEELS 6 10560FT/TRIP WET DAYS/YR 110 DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 4.00 6.74 LB/VMT 100T/HR 2.70E-01 5.39E+01 NONE 0 2.70E-01 5.39E+01 REFUSE HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1000T/YR ONE-WAY EMPTY (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 56 25T/TRIP NO. OF WHEELS 10 10560FT/TRIP WET DAYS/YR 110

DUMP TRUCK CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 9.39E-05 1.88E-02 NONE 0 9.39E-05 1.88E-02 FEED TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1000T/YR

**EMISSIONS SUB-TOTAL 5.40E-01**  **1.08E+02 5.40E-01**  **1.08E+02**

INSIGNIF. RAILCAR UNLOADER RAILCAR FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.05E-01 1.88E-01 PARTIAL 50 5.26E-02 9.39E-02 EMISSION TO SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR ENCLOSURE SOURCE SURGE HOPPER FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.05E-01 1.88E-01 ENCLOSURE 70 3.16E-02 5.64E-02 TO BC-3 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR

**EMISSIONS SUB-TOTAL 2.10E-01**  **3.76E-01 8.42E-02**  **1.50E-01**

INSIGNIF. BUNKERS BC-16 , BC-17, BC--26 OR CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 6.54E-01 1.88E-01 ENCLOSURE 70 1.96E-01 5.64E-02 EMISSION BC--27 FEED TO BUNKERS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.96E+06T/YR SOURCE 19 TRACTOR TRUCK COAL HAULING UNPAVED ROAD SILT CONTENT, % 9.6 30.20 LB/VMT 4300T/HR 2.19E+03 7.55E+03 WET 95 1.09E+02 3.77E+02

UNLOADING ONE-WAY FULL FUGITIVE DUST VEHICLE SPEED, MPH 20 2.49E+06T/YR SUPPRESSION SYSTEM (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 59.5 43T/TRIP NO. OF WHEELS 18 2.5MI/TRIP WET DAYS/YR 110 TRUCK COAL HAULING UNPAVED ROAD SILT CONTENT, % 9.6 12.30 LB/VMT 4300T/HR 8.91E+02 3.08E+03 WET 95 4.45E+01 1.54E+02 ONE-WAY EMPTY FUGITIVE DUST VEHICLE SPEED, MPH 20 2.49E+06T/YR SUPPRESSION (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 16.5 43T/TRIP NO. OF WHEELS 18 2.5MI/TRIP WET DAYS/YR 110

WATER TRUCK UNPAVED ROAD SILT CONTENT, % 9.6 25.96 LB/VMT 15VMT/HR 6.07E+02 3.89E+02 WET 95 3.04E+01 1.95E+01 DUST SUPPRESSION FUGITIVE DUST VEHICLE SPEED, MI/HR 15 3.12E+03 HR/YR SUPPRESSION DUST SUPPRESSION FUGITIVE DUST VEHICLE SPEED, MI/HR 3.12E+03 SUPPRESSION ON HAUL ROADS (AP-42, SEC. 11.2.1) VEHICLE WEIGHT EMPTY, T 85 VEHICLE WEIGHT, T 135.04 CAPACITY, T 50.04 AVERAGE HAUL WEIGHT, T 110.02 NUMBER OF WHEELS 10 WET DAYS/YR 110 TRUCK DUMP TO BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 4300T/HR 2.34E-01 8.08E-01 NONE 0 2.34E-01 8.08E-01 SHORT-TERM STORAGE PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.49E+06T/YR

FRONT-END LOADER UNPAVED ROAD SILT CONTENT, % 4 0.79LB/VMT 3380HR/YR 2.68E+00 1.59E+00 NONE 0 2.68E+00 1.59E+00 STOCKOUT/RECLAIM FUGITIVE DUST VEHICLE SPEED, MPH 2 6.76E+03MILES/YR AND PILE MAINT ACTIVITIES (AP-42, SEC. 11.2.1) AVG VEHICLE WEIGHT, T 90.15 NO. OF WHEELS 4 WET DAYS/YR 110 FRONT-END LOADER BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 4300T/HR 2.34E-01 8.08E-01 NONE 0 2.34E-01 8.08E-01 FEED TO SHORT-TERM PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.49E+06T/YR

OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49LB/ACRE-D 2.1ACRE 9.40E-01 2.15E-01 NONE 0 9.40E-01 2.15E-01 FREQ-DISTURBD PILE WET DAYS/YR 110 (EPA, 1992, SEC. 2.3.1.3.3)WIND FREQ > 12 MPH, % 7.6 FRONT-END LOADER BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.34E-01 3.76E-01 PARTIAL 50 1.17E-01 1.88E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.49E+06T/YR ENCLOSURE HOPPER #1 OR #2 TRUCK HOPPER #1 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 70 3.51E-02 5.64E-02 FEED TO BC-1 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR

TRUCK HOPPER #2 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 70 3.51E-02 5.64E-02 FEED TO BC-2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR

**EMISSIONS SUB-TOTAL 3.69E+03**  **1.10E+04 1.88E+02**  **5.54E+02**

Page 1 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 20 BREAKER BC-1 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 97 3.51E-03 5.64E-03

BUILDING BREAKER NO. 1 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR FOAM (BREAKERS NO. 1 & 2) SUPPRESSION BC-2 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 97 3.51E-03 5.64E-03 BREAKER NO. 2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR FOAM SUPPRESSION BREAKER NO. 1 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 1.24E+01 2.00E+01 ENCLOSURE 97 3.73E-01 6.00E-01 (AP-42 SEC. 8.23) 1.24E+06T/YR FOAM SUPPRESSION BREAKER NO. 2 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 1.24E+01 2.00E+01 ENCLOSURE 97 3.73E-01 6.00E-01 (AP-42 SEC. 8.23) 1.24E+06T/YR FOAM SUPPRESSION BREAKERS FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 94 7.02E-03 1.13E-02 TO BC-7 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR FOAM 1ST CARRYOVER BREAKERS FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.17E-01 1.88E-01 ENCLOSURE 94 7.02E-03 1.13E-02 TO BC-8 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.24E+06T/YR FOAM 1ST CARRYOVER BREAKERS FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 9.39E-05 1.88E-02 ENCLOSURE 94 5.64E-06 1.13E-03 BC-20 (REFUSE CONV) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03T/YR FOAM 1ST CARRYOVER BC-20 (REFUSE CONV) CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 9.39E-05 1.88E-02 PARTIAL 85 1.41E-05 2.82E-03 FEED TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03T/YR ENCLOSURE FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 2.54E+01**  **4.08E+01 7.68E-01**  **1.24E+00**

21 BREAKER BUILDING BC-3 FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.05E-01 1.88E-01 ENCLOSURE 97 3.16E-03 5.64E-03

(BREAKER NO. 3) TO BREAKER NO.3 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR FOAM SUPPRESSION BREAKER No. 3 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 1.12E+01 2.00E+01 ENCLOSURE 97 3.36E-01 6.00E-01 (AP-42 SEC. 8.23) 1.12E+06T/YR FOAM SUPPRESSION BREAKER NO.3 FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.05E-01 1.88E-01 ENCLOSURE 94 6.31E-03 1.13E-02 TO BC-4 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR FOAM 1ST CARRYOVER BREAKER NO.3 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 4.70E-05 1.88E-02 PARTIAL 90 4.70E-06 1.88E-03 RC-1 (REFUSE CONV) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.00E+02T/YR ENCLOSURE FOAM 1ST CARRYOVER **EMISSIONS SUB-TOTAL 1.14E+01**  **2.04E+01 3.46E-01**  **6.19E-01**

22 TRANSFER STN A BC-7 AND BC-8 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.34E-01 3.76E-01 ENCLOSURE 91 2.10E-02 3.38E-02 BC-9, BC-12, BC-19, OR BC-31 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.49E+06T/YR FOAM 2ND CARRYOVER BC-45 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.18E-01 3.76E-01 ENCLOSURE 70 3.54E-02 1.13E-01 BC-9, BC-12 OR BC-19 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.26E+06T/YR

BC-18 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.58E-01 3.76E-01 ENCLOSURE 94 9.50E-03 2.25E-02 BC-9 OR BC-12 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.68E+06T/YR FOAM 1ST CARRYOVER SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 2.55E+00T/HR 7.93E-02 1.27E-01 ENCLOSURE 70 2.38E-02 3.82E-02 BC-7 AND BC-8 SAMPLER (AP-42, SEC. 8.23) 3.17E+03T/YR

**EMISSIONS SUB-TOTAL 5.89E-01**  **1.25E+00 8.97E-02**  **2.07E-01**

23 TRANSFER BC-4 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.05E-01 1.88E-01 ENCLOSURE 91 9.47E-03 1.69E-02

STATION B BC-28 OR BC-44 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR FOAM 2ND CARRYOVER BC-30 FEED TO BC-44 CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 1000T/HR 0.00E+00 3.28E-01 ENCLOSURE 70 0.00E+00 9.83E-02 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

BC-43A TO BC-28 CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 1.5T/HR 4.20E-02 7.50E-02 ENCLOSURE 70 1.26E-02 2.25E-02 BC-4 SAMPLER (AP-42, SEC. 8.23) 1.68E+03T/YR

**EMISSIONS SUB-TOTAL 1.47E-01**  **1.25E+00 2.21E-02**  **3.34E-01**

Page 2 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 24 OPEN LIVE BC-28 OR BC-29 FEED CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 PARTIAL 50 0.00E+00 3.28E-01

STORAGE PILE TO LIVE PILE NO.3 OR 4 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR ENCLOSURE LIVE PILE No. 3 & 4 BC-28 FEED TO BC-29 CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49LB/ACRE-D 1 ACRE 4.55E-01 1.04E-01 NONE 0 4.55E-01 1.04E-01 FREQ-DISTURBD PILE WET DAYS/YR 110 (EPA, 1992, SEC. 2.3.1.3.3)WIND FREQ > 12 MPH, % 7.6 LIVE PILE No. 3 OR 4 HOPPERCONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 1000T/HR 0.00E+00 3.28E-01 ENCLOSURE 70 0.00E+00 9.83E-02 FEED TO BC-30 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

**EMISSIONS SUB-TOTAL 4.55E-01**  **1.74E+00 4.55E-01**  **7.27E-01**

25 TRANSFER STATN G BC-31 FEED TO BC-32 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 88 0.00E+00 4.51E-02 OR BC-43A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 3RD CARRYOVER

BC-43 FEED TO BC-45 OR CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 TO BC-43A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

BC-44 FEED TO CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 1000T/HR 1.84E-01 3.28E-01 ENCLOSURE 70 5.51E-02 9.83E-02 BC-32 OR BC-45 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.12E+06T/YR

**EMISSIONS SUB-TOTAL 1.84E-01**  **1.36E+00 5.51E-02**  **3.40E-01**

26 TRANSFER STATN H BC-54 AND BC-32 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 4000T/HR **0.00E+00 7.51E-01**  ENCLOSURE 97 **0.00E+00 2.25E-02**  BC-33, BC-35 OR BC-47 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM SUPPRESSION 27 COAL STORAGE BC-33 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 94 0.00E+00 2.25E-02

SILOS 5 & 6 STORAGE SILO #5 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 1ST CARRYOVER BC-33 FEED TO BC-34 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 94 0.00E+00 2.25E-02 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 1ST CARRYOVER BC-34 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 91 0.00E+00 3.38E-02 STORAGE SILO #6 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 2nd CARRYOVER SILOS FEED TO BC-35 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 88 0.00E+00 4.51E-02 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 3RD (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 0.00E+00 FOAM 3RD CARRYOVER **EMISSIONS SUB-TOTAL 0.00E+00**  **1.50E+00 0.00E+00**  **1.24E-01**

28 TRANSFER STATN J BC-35 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 85 0.00E+00 5.64E-02 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR FOAM 4TH BC-36 AND BC-37 CARRYOVER BC-46 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 70 0.00E+00 1.13E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR BC-36 AND BC-37 **EMISSIONS SUB-TOTAL 0.00E+00**  **7.51E-01 0.00E+00**  **1.69E-01**

29 TRANSFER STATN K BC-36 AND BC-37 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 70 0.00E+00 1.13E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR BC-38, BC-39 AND SCREENS BC-38 AND BC-39 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 0.00E+00 1.88E-01 ENCLOSURE 70 0.00E+00 5.64E-02 FEED TO SCREENS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR (WASH PLANT) **EMISSIONS SUB-TOTAL 0.00E+00**  **5.64E-01 0.00E+00**  **1.69E-01**

30 TRANSFER STATN L BC-41 FEED TO CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

SURGE HOPPER CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 FEED TO BC-42 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 1.545T/HR 0.00E+00 7.73E-02 ENCLOSURE 70 0.00E+00 2.32E-02 BC-41 SAMPLER (AP-42, SEC. 8.23) 0.00E+00T/YR

**EMISSIONS SUB-TOTAL 0.00E+00**  **1.39E+00 0.00E+00**  **4.17E-01**

31 TRANSFER STATN M BC-42 FEED TO BC-43 CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR **0.00E+00 6.56E-01**  ENCLOSURE 70 **0.00E+00 1.97E-01**  (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

Page 3 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 32 BARGE UNLOADER/ BARGE UNLOADER CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 4000T/HR 2.72E-01 7.51E-01 WATER SPRAY 80 5.44E-02 1.50E-01

SURGE HOPPER DUMP TO BC-49 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR

BC-49 DUMP TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 4000T/HR 2.72E-01 7.51E-01 ENCLOSURE 70 8.16E-02 2.25E-01 SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR

HOPPER DUMP TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.72E-01 3.76E-01 ENCLOSURE 70 8.16E-02 1.13E-01 BC-50 AND BC-51 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR

**EMISSIONS SUB-TOTAL 8.16E-01**  **1.88E+00 2.18E-01**  **4.88E-01**

33 TRANSFER STATION N BC-50 & BC-51 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.72E-01 3.76E-01 ENCLOSURE 97 8.16E-03 1.13E-02

(BREAKERS NO. 4-7) BREAKERS 4-7 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR FOAM SUPPRESSION BREAKERS 4-7 PRIMARY CRUSHER

--- --- 0.02LB/T 2000T/HR 2.90E+01 4.00E+01 ENCLOSURE 97 8.69E-01 1.20E+00 (AP-42, SEC. 8.23) 2.90E+06T/YR FOAM SUPPRESSION BREAKERS FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.72E-01 3.76E-01 ENCLOSURE 94 1.63E-02 2.25E-02 TO BC-52 & BC-53 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR FOAM 1ST CARRYOVER BREAKERS FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 9.39E-05 1.88E-02 ENCLOSURE 94 5.64E-06 1.13E-03 REFUSE CONVEYORS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03T/YR FOAM 1ST CARRYOVER SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 4.219T/HR 1.53E-01 2.11E-01 ENCLOSURE 70 4.58E-02 6.33E-02 BC-50 & BC-51 SAMPLER (AP-42, SEC. 8.23) 6.11E+03T/YR

REFUSE CONVEYORS CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 100T/HR 9.39E-05 1.88E-02 PART ENCL. 85 1.41E-05 2.82E-03 FEED TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03T/YR FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 2.96E+01**  **4.10E+01 9.39E-01**  **1.30E+00**

34 TRANSFER STATN P BC-52 AND BC-53 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.72E-01 3.76E-01 ENCLOSURE 91 2.45E-02 3.38E-02

& STORAGE BYPASS FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.90E+06T/YR FOAM 2ND BC-54 OR BC-55 CARRYOVER

BC-55 FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.46E-01 3.76E-01 ENCLOSURE 97 7.38E-03 1.13E-02 TO BC-55A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.62E+06T/YR FOAM (STORAGE BYPASS CONV.) SUPPRESSION

BC-55A FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.46E-01 3.76E-01 ENCLOSURE 94 1.48E-02 2.25E-02 BC-18 (RECLAIM CONV.) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.62E+06T/YR FOAM 1ST CARRYOVER **EMISSIONS SUB-TOTAL 7.64E-01**  **1.13E+00 4.66E-02**  **6.76E-02**

35 LONG-TERM OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49LB/ACRE-D 35ACRE 1.59E+01 3.63E+00 NONE 0 1.59E+01 3.63E+00

COAL STORAGE YARD FREQ-DISTURBD PILE WET DAYS/YR 110 (EPA, 1992, SEC. 2.3.1.3.3)WIND FREQ > 12 MPH, % 7.6 BC-19 STOCKOUT BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.11E-01 3.76E-01 PARTIAL 50 5.54E-02 1.88E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.18E+06T/YR ENCLOSURE PAN SCRAPERS BC-55 STOCKOUT BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.59E-02 3.76E-01 PARTIAL 95 1.30E-03 1.88E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.76E+05T/YR ENCLOSURE PAN SCRAPERS FOAM SUPPRESSION BC-47 STOCKOUT BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 PARTIAL 90 0.00E+00 3.76E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR ENCLOSURE PAN SCRAPERS FOAM 1ST CARRYOVER PAN SCRAPERS UNPAVED ROAD SILT CONTENT, % 4 7.60 LB/VMT 2000T/HR 1.01E+01 2.77E+01 WET 75 2.52E+00 6.92E+00 STOCKOUT HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1.46E+06T/YR SUPPRESSION ONE-WAY FULL (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 128 52T/TRIP NO. OF WHEELS 4 500FT/TRIP WET DAYS/YR 110 PAN SCRAPERS UNPAVED ROAD SILT CONTENT, % 4 5.28LB/VMT 2000T/HR 6.99E+00 1.92E+01 WET 75 1.75E+00 4.80E+00 STOCKOUT HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1.46E+06T/YR SUPPRESSION ONE-WAY EMPTY (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 76 52T/TRIP NO. OF WHEELS 4 500FT/TRIP WET DAYS/YR 110

PAN SCRAPERS BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.37E-01 3.76E-01 NONE 0 1.37E-01 3.76E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.46E+06T/YR STORAGE PILE

Page 4 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 35 LONG-TERM PAN SCRAPERS UNPAVED ROAD SILT CONTENT, % 4 7.60 LB/VMT 2000T/HR 1.17E+01 2.77E+01 WET 75 2.92E+00 6.92E+00 (CONT'D) COAL STORAGE YARD RECLAIM HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1.68E+06T/YR SUPPRESSION

(CONTINUED) ONE-WAY FULL (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 128 52T/TRIP NO. OF WHEELS 4 500FT/TRIP WET DAYS/YR 110

PAN SCRAPERS UNPAVED ROAD SILT CONTENT, % 4 5.28LB/VMT 2000T/HR 8.09E+00 1.92E+01 WET 75 2.02E+00 4.80E+00 RECLAIM HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 1.68E+06T/YR SUPPRESSION ONE-WAY EMPTY (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 76 52T/TRIP NO. OF WHEELS 4 500FT/TRIP WET DAYS/YR 110

PAN SCRAPERS BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.58E-01 3.76E-01 NONE 0 1.58E-01 3.76E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.68E+06T/YR RECLAIM HOPPER BC-18 RECLAIM HOPPER BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 1.58E-01 3.76E-01 ENCLOSURE 97 4.75E-03 1.13E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.68E+06T/YR FOAM BC-18 SUPPRESSION

STORAGE PILE UNPAVED ROAD SILT CONTENT, % 4 0.45LB/VMT 416HR/YR 1.87E-01 8.98E-01 NONE 0 1.87E-01 8.98E-01 MAINTENANCE FUGITIVE DUST VEHICLE SPEED, MPH 2 8.32E+02VMT/YR DOZERS (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 40.0 NO. OF WHEELS 4 WET DAYS/YR 110 PAN SCRAPERS BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 NONE 0 0.00E+00 3.76E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR RECLAIM HOPPER BC-46 RECLAIM HOPPER BATCH DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 0.00E+00 3.76E-01 ENCLOSURE 70 0.00E+00 1.13E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR BC-46

PILE WATERING UNPAVED ROAD SILT CONTENT, % 4 1.65LB/VMT 5VMT/HR 8.58E+00 8.25E+00 WET 75 2.15E+00 2.06E+00 DUST SUPPRESSION FUGITIVE DUST VEHICLE SPEED, MI/HR 5 2.08E+03 HR/YR SUPPRESSION ON HAUL ROADS (AP-42, SEC. 11.2.1) VEHICLE WEIGHT EMPTY, T 48.5 VEHICLE WEIGHT, T 90.2 CAPACITY, T 41.7 AVERAGE HAUL WEIGHT, T 69.35 NUMBER OF WHEELS 4 WET DAYS/YR 110 **EMISSIONS SUB-TOTAL 6.21E+01**  **1.10E+02 2.78E+01**  **3.15E+01**

36 COVERED LIVE BC-9 FEED TO SILO # 1 OR CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 4.80E-01 3.76E-01 ENCLOSURE 70 1.44E-01 1.13E-01

STORAGE SILOS BC-10 FEED TO SILO #2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.11E+06T/YR (SILOS #1 and #2) BC-9 TO BC-10 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 2.40E-01 3.76E-01 ENCLOSURE 70 7.20E-02 1.13E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.55E+06T/YR

SILO #1 or #2 TO BC-11 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 4.80E-01 3.76E-01 ENCLOSURE 70 1.44E-01 1.13E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.11E+06T/YR

**EMISSIONS SUB-TOTAL 1.20E+00**  **1.13E+00 3.60E-01**  **3.38E-01**

37 OLD CONDITIONERS BC-11 OR BC-12 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 4.80E-01 3.76E-01 ENCLOSURE 97 1.44E-02 1.13E-02

(CRUSHERS) TO SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.11E+06T/YR FOAM SUPPRESSION SURGE HOPPER TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 4.80E-01 3.76E-01 ENCLOSURE 94 2.88E-02 2.25E-02 CONDITIONERS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.11E+06T/YR FOAM 1ST CARRYOVER CONDITIONERS SECONDARY CRUSHER

--- --- 0.05LB/T 2000T/HR 1.28E+02 1.00E+02 ENCLOSURE 94 7.66E+00 6.00E+00 (4 WITH ONE SPARE) AP-42 SEC. 8.23 5.11E+06T/YR FOAM 1ST CARRYOVER CONDITIONERS FEED CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 4.80E-01 3.76E-01 ENCLOSURE 91 4.32E-02 3.38E-02 TO BC-13 AND BC-14 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.11E+06T/YR FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 1.29E+02**  **1.01E+02 7.75E+00**  **6.07E+00**

38 POWERHOUSE BC-13 AND BC-14 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 2000T/HR 6.54E-01 3.76E-01 ENCLOSURE 88 7.84E-02 4.51E-02

TRANSFER STATIONS BC-15, BC-17, OR BC-22 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.96E+06T/YR FOAM 3RD CARRYOVER BC-15 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 3.27E-01 1.88E-01 ENCLOSURE 85 4.90E-02 2.82E-02 BC-16 OR BC-23 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.48E+06T/YR FOAM 4TH CARRYOVER BC-23 OR BC-24 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.46E-01 1.88E-01 ENCLOSURE 70 4.39E-02 5.64E-02 BC-25 OR BC-27 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.56E+06T/YR

Page 5 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 38 POWERHOUSE BC-25 TO BC-26 CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 2.93E-02 1.88E-01 ENCLOSURE 70 8.78E-03 5.64E-02 (CONT'D) TRANSFER STATIONS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.12E+05T/YR

BC-22 FEED TO CONT. DROP H2O CONTENT, % 16.4 1.88E-04LB/T 1000T/HR 1.46E-01 1.88E-01 ENCLOSURE 85 2.20E-02 2.82E-02 BC-24 OR BC-26 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.56E+06T/YR FOAM 4TH CARRYOVER **EMISSIONS SUB-TOTAL 1.30E+00**  **1.13E+00 2.02E-01**  **2.14E-01**

39 COAL WASH PLANT FEED FROM HOPPERS CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01

(CLEAN COAL) T0 BC-40 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

BC-40 FEED CONT. DROP H2O CONTENT, % 11 3.28E-04LB/T 2000T/HR 0.00E+00 6.56E-01 ENCLOSURE 70 0.00E+00 1.97E-01 TO BC-41 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

MAGNETITE FEED FROM CONT. DROP H2O CONTENT, % 2 3.57E-03LB/T 25T/HR 0.00E+00 8.91E-02 ENCLOSURE 70 0.00E+00 2.67E-02 DELIVERY TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

REFUSE FEED FROM WASH CONT. DROP H2O CONTENT, % 10 3.75E-04LB/T 400T/HR 0.00E+00 1.50E-01 ENCLOSURE 70 0.00E+00 4.50E-02 PLANT TO REFUSE CONV. (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

**EMISSIONS SUB-TOTAL 0.00E+00**  **1.55E+00 0.00E+00**  **4.65E-01**

40 COAL WASH PLANT REFUSE CONVEYOR FEED TOBATCH DROP H2O CONTENT, % 10 3.75E-04LB/T 400T/HR 0.00E+00 1.50E-01 PARTIAL 50 0.00E+00 7.49E-02

COARSE REFUSE DUMP TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR ENCLOSURE DISPOSAL DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 9.6 16.78LB/VMT 400T/HR 0.00E+00 1.01E+02 WET 95 0.00E+00 5.04E+00

REFUSE HAULING ON FUGITIVE DUST VEHICLE SPEED, MPH 15 0.00E+00T/YR SUPPRESSION HAUL ROAD (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 85 50T/TRIP ONE-WAY FULL NO. OF WHEELS 6 0.75MI/TRIP WET DAYS/YR 110

DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 0 0.00 LB/VMT 400T/HR 0.00E+00 0.00E+00 NONE 0 0.00E+00 0.00E+00 REFUSE HAULING ON FUGITIVE DUST VEHICLE SPEED, MPH 15 0.00E+00T/YR REFUSE PILE (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 85 50T/TRIP ONE-WAY FULL NO. OF WHEELS 6 0.35MI/TRIP WET DAYS/YR 110 DUMP TRUCK BATCH DROP H2O CONTENT, % 10 3.75E-04LB/T 400T/HR 0.00E+00 1.50E-01 NONE 0 0.00E+00 1.50E-01 DISCHARGE TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00T/YR

DOZER SPREADING UNPAVED ROAD SILT CONTENT, % 0 0.00 LB/VMT 3120HR/YR 0.00E+00 0.00E+00 NONE 0 0.00E+00 0.00E+00 DOZER SPREADING UNPAVED ROAD SILT CONTENT, % 0.00E+00 0.00E+00 0.00E+00 0.00E+00 COARSE REFUSE FUGITIVE DUST VEHICLE SPEED, MPH 2 6.24E+03VMT/YR (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 40 NO. OF WHEELS 4 WET DAYS/YR 110 OPEN STORAGE WIND EROSION OF SILT CONTENT, % 0 0.00 LB/ACRE-D 40ACRE 0.00E+00 0.00E+00 NONE 0 0.00E+00 0.00E+00 FREQ-DISTURBD PILE WET DAYS/YR 110 (EPA, 1992, SEC. 2.3.1.3.3)WIND FREQ > 12 MPH, % 7.6 DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 0 0.00 LB/VMT 400T/HR 0.00E+00 0.00E+00 NONE 0 0.00E+00 0.00E+00 REFUSE HAULING ON PILE FUGITIVE DUST VEHICLE SPEED, MPH 15 0.00E+00T/YR ONE-WAY EMPTY (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 35 50T/TRIP NO. OF WHEELS 6 0.35MI/TRIP WET DAYS/YR 110 DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 9.6 9.02 LB/VMT 400T/HR 0.00E+00 1.02E-02 WET 95 0.00E+00 5.12E-04 REFUSE HAULING ON FUGITIVE DUST VEHICLE SPEED, MPH 15 0.00E+00T/YR SUPPRESSION HAUL ROAD (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 35 50T/TRIP ONE-WAY EMPTY NO. OF WHEELS 6 0.75MI/TRIP WET DAYS/YR 110 **EMISSIONS SUB-TOTAL 0.00E+00**  **1.01E+02 0.00E+00**  **5.26E+00**

**CY06 PAF SOLID-FUEL-HANDLING SYSTEM PARTICULATE-MATTER (PM) EMISSION TOTALS:**

UNCONTROLLED TSP CONTROLLED TSP T/YR LB/HR T/YR LB/HR

POINT-SOURCE 0.00E+00 0.00E+00 0.00E+00 0.00E+00

FUGITIVE 3.95E+03 1.16E+04 2.28E+02 7.13E+02

------------ ------------ ------------ ------------

**3.95E+03 1.16E+04**  **2.28E+02 7.13E+02** 

Page 6 of 7coal



### Table 4-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 SOLID-FUEL-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION PM SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR

**NOTES:** References (1) The sources of emission equations/factors are:

(a) Material drop operations (continuous and batch) EPA, AP-42, 4th Edition, Section 11.2.3, 1988
(b) Unpaved roads EPA, AP-42, 4th Edition, Section 11.2.1, 1988
(c) Coal crushers, primary and secondary (high-moisture material) EPA, AP-42, 4th Edition, Section 8.23, 1982
(d) Wind erosion from active (frequently disturbed) piles EPA, Fugitive Dust Background Document and Technical Information Document for Best Available Control Measures, 1992.
(2) The sources for meteorological input parameters are:

(a) Average wind speed (6.85 mph) and frequency of winds greater than 12 mph (7.6 %) Paradise Fossil Plant Meteorological Tower, 1985-86 Data Base
(b) Number of wet days per year (110) National Weather Service, Paducah, Kentucky Airport Data, 1984-94 Average
(3) The sources of control efficiencies are:

(a) Wet suppression (haul road fugitive dust) 75-95 %(AWMA, Air Pollution Engineering Manual, p. 143-144, 1992)
(b) Water spray (barge unloader) 80 % (DOE/RG/10312-1 (Vol. 2), Technical Guide for Estimating Fugitive Dust Impacts from Coal Handling Operations, p. 4-3, 1984)
(c) Enclosure of conveyors and transfer points 70% (AWMA, Air Pollution Engineering Manual, p. 794, 1992)
(d) Foam suppression 90% (AWMA, Air Pollution Engineering Manual, p. 794, 1992)
(e) Foam suppression - 1st carryover 80% Engineering Estimate
(f) Foam suppression - 2nd carryover 70% Engineering Estimate
(g) Foam suppression - 3rd carryover 60% Engineering Estimate
(h) Foam suppression - 4th carryover 50% Engineering Estimate
(i) Partial enclosure 50% Engineering Estimate

*Reference: CY05 Particulate-Matter (PM) Emission Estimates (expressed as Total Suspended Particulates [TSP]), adapted** from 12-3-96 Title V Permit Application for Paradise Fossil Plant (PAF). TVA Environmental Technologies ** Reference: Excel file "Coal and Limestone Handled in CY 2005.xls" in 2-3-06 e-mail from S.L. Priddy to C.M. Anderson et al. 03/26/07

Page 7 of 7

### Lstone



### Table 5-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 LIMESTONE- AND LIME-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES*

EMISSION EMISSION APPLICABLE INPUT PARAMETERS (2) UNCONTROLLED CONTROLLED UNIT UNIT EMISSION SCALING FACTOR PM EMISSIONS % CONTROL PM EMISSIONS NUMBER DESCRIPTION COMPONENT EQUATION (1) PARAMETER VALUE EMISSIONFACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 41 LIMESTONE RAIL/ TRUCK LIMESTONE UNPAVED ROAD SILT CONTENT, % 9.6 11.5 LB/VMT 900T/HR 3.10E+02 1.18E+03 WET 95 1.55E+01 5.90E+01

TRUCK UNLOADING HAULING ONE-WAY EMPTY FUGITIVE DUST VEHICLE SPEED, MPH 20 4.73E+05T/YR SUPPRESSION SYSTEM (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 15 25T/TRIP NO. OF WHEELS 18 2.85MI/TRIP WET DAYS/YR 110

TRUCK LIMESTONE UNPAVED ROAD SILT CONTENT, % 9.6 22.9 LB/VMT 900T/HR 6.16E+02 2.35E+03 WET 95 3.08E+01 1.17E+02 HAULING ONE-WAY FULL FUGITIVE DUST VEHICLE SPEED, MPH 20 4.73E+05T/YR SUPPRESSION (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 40 25T/TRIP NO. OF WHEELS 18 2.85MI/TRIP WET DAYS/YR 110

DISCHARGE FROM CONT. DROP H2O CONTENT, % 3.1 1.93E-03 LB/T 900T/HR 4.56E-01 1.74E+00 NONE 0 4.56E-01 1.74E+00 RAILCAR/TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.73E+05T/YR TO HOPPER

**EMISSIONS SUB-TOTAL 9.26E+02**  **3.53E+03 4.68E+01**  **1.78E+02**

42 RECLAIM/RECEIVING BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 3600SCF/MIN 2.70E+02 6.17E+01 BAG FILTER 99 2.70E+00 6.17E-01

HOPPER FEEDER VENT INFORMATION: OUTLET PER VENT BAGFILTER (DC-1) GRAIN LOADING 1COLLECTR 8760HR/YR

43-44 TRANSFER STATION BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 3700SCF/MIN 5.56E+02 1.27E+02 BAG FILTER 99 5.56E+00 1.27E+00

BAGFILTERS VENTS INFORMATION: OUTLET PER VENT (DC-2A, 2B) GRAIN LOADING 2COLLECTRS 8760HR/YR

45 LIMESTONE STORAGE BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 2000SCF/MIN 1.50E+02 3.43E+01 BAG FILTER 99 1.50E+00 3.43E-01

SILO BIN VENT FILTER VENT INFORMATION: OUTLET PER VENT (DC-3) GRAIN LOADING 1COLLECTR 8760HR/YR

46-48 LIMESTONE STORAGE BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 4000SCF/MIN 9.01E+02 2.06E+02 BAG FILTER 99 9.01E+00 2.06E+00

SILO VIBRATING FEEDER VENTS INFORMATION: OUTLET PER VENT BAGFILTERS (DC-4A, 4B, 4C) GRAIN LOADING 3COLLECTRS 8760HR/YR

49-51 LIMESTONE PREP BLDG DISCHARGE FROM CONT. DROP H2O CONTENT, % 3.1 1.93E-03 LB/T 720T/HR 8.97E-01 1.39E+00 ENCLOSURE 70 2.69E-01 4.17E-01 CONVEYORS N-306-A,-B, & -C(AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 9.30E+05T/YR

Page 1 of 2 CONVEYORS N-306-A,-B, & -C(AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 9.30E+05T/YR TO SURGE HOPPERS

52 LIMESTONE HANDLING DISCHARGE TO STORAGE CONT. DROP H2O CONTENT, % 3.1 1.93E-03 LB/T 900T/HR 4.41E-01 1.74E+00 TELESCOPING 50 2.21E-01 8.69E-01

BULK STORAGE PILE PILE FROM CONVEYOR (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.57E+05T/YR CHUTE

OPEN STORAGE WIND EROSION OF SILT CONTENT, % 5 3.12E+00 LB/ACRE-D 4.00ACRE OF 2.27E+00 5.19E-01 NONE 0 2.27E+00 5.19E-01 FREQ-DISTURBD PILE WET DAYS/YR 110 DISTURBED (EPA, 1992, SEC 2.3.1.3.3)WIND FREQ > 12 MI/HR, % 7.6 PILE AREA

LIMESTONE RECLAIM UNPAVED ROAD SILT CONTENT, % 5 9.12E-01 LB/VMT 2VMT/HR 7.59E-01 1.82E+00 NONE 0 7.59E-01 1.82E+00 (BULLDOZER) FUGITIVE DUST VEHICLE SPEED, MI/HR 2 832HR/YR (AP-42, SEC. 11.2.1) VEHICLE WEIGHT, T 80 NUMBER OF WHEELS 4 WET DAYS/YR 110 **EMISSIONS SUB-TOTAL 3.47E+00**  **4.08E+00 3.25E+00**  **3.21E+00**

53-54 LIME STORAGE SILO BAGFILTER

--- ENG. ESTIMATE

--- 2.00E-02 GR/SCF 1150SCF/MIN 1.38E+00 3.94E+01 BAG FILTER 99 1.38E-02 3.94E-01

BAGFILTERS VENTS OUTLET PER VENT GRAIN LOADING 2COLLECTRS 70HR/YR

**PAF LIMESTONE/LIME HANDLING SYSTEMS PARTICULATE-MATTER (TSP) EMISSION TOTALS:**

UNCONTROLLED TSP CONTROLLED TSP T/YR LB/HR T/YR LB/HR

POINT-SOURCE 1.88E+03 4.68E+02 1.88E+01 4.68E+00

ON-PERMIT FUGITIVES 4.83E+00 7.21E+00 3.98E+00 5.37E+00 OFF-PERMIT FUGITIVES 9.26E+02 3.53E+03 4.63E+01 1.76E+02 FUGITIVE TOTAL 9.31E+02 3.53E+03 5.03E+01 1.82E+02

------------ ------------ ------------ ------------ ON-PERMIT TOTAL **1.88E+03 4.75E+02**  **2.28E+01 1.00E+01**  Page 1 of 2

### Lstone



### Table 5-2. PARADISE FOSSIL PLANT (PAF): ACTUAL CY05 LIMESTONE- AND LIME-HANDLING PARTICULATE-MATTER (PM) EMISSION ESTIMATES* (Cont'd)

NOTES: References (1) The sources of emission equations/factors are:
(a) Material drop operations (continuous and batch) EPA, AP-42, 4th Edition, Section 11.2.3, 1988
(b) Unpaved roads EPA, AP-42, 4th Edition, Section 11.2.1, 1988
(c) Wind erosion from active (frequently disturbed) piles EPA, Fugitive Dust Background Document and Technical Information Document for Best Available Control Measures,1992.
(d) Bagfilter outlet grain loading Manufacturer's Information
(2) The sources for meteorological input parameters are:
(a) Average wind speed (6.85 mph) and frequency of winds greater than 12 mph (7.6 %) Paradise Fossil Plant Meteorological Tower, 1985-86 Data Base
(b) Number of wet days per year (110) National Weather Service, Paducah, Kentucky Airport Data, 1984-94 Average
(3) The sources of control efficiencies are:
(a) Telescoping chute on stockout 50% (Engineering Estimate)
(b) Bagfilter >99% (Manufacturer's Information)
(c) Wet suppression (for haul roads) 95 % (AWMA, Air Pollution Engineering Manual, p. 143-144, 1992)
(d) Enclosure of conveyors and transfer points 70% (AWMA, Air Pollution Engineering Manual, p. 794, 1992)



### *Reference: CY05 Particulate-Matter (PM) Emission Estimates (expressed as Total Suspended Particulates [TSP]), adapted** from 12-3-96 Title V Permit Application for Paradise Fossil Plant (PAF). TVA Environmental Technologies 

### ** Reference: 1-22-04 Conference Call between J.W. Osborne, B.L. Barnard, & J.D. Lokey (& subsequent voice mail from J.W. Osborne). 03/26/07

Page 2 of 2

# ash

**Paradise Fossil Plant (PAF) Ash Handling***
**Process Description:** Bottom ash (slag) flows from the furnaces into slag tanks equipped with clinker grinders underneath that crush the slag into smaller particles. Fly ash collected in the economizer hoppers falls into a Denslury pot (water-impounded tub) from which it is sluiced to the slag tanks. The wet slurry in the slag tanks is sluiced by Jetpulsion pumps to the slag pond. Fugitive dust emissions from the powerhouse portion of the slag handling system are judged to be negligible since it is wet and completely enclosed. The mixture of bottom ash and economizer ash is reclaimed from the slag pond using a front-end loader and stacked in the dewatering area. After the ash has sufficiently dewatered, it is loaded out to trucks using a front-end loader and hauled offsite for use in the customer's process. In addition, the customer has been recovering previously disposed slag in a mining/processing operation located elsewhere on the PAF reservation. This facility is completely separate from PAF operations, and no emission estimates for this facility were included in the 12-3-96 Title V permit application.
Fly ash collected in gas-duct, air-preheater, and electrostatic-precipitator (ESP) hoppers is evacuated by hydroveyors. The hydroveyors use water to create a vacuum & move the ash and conveying air to air separator tanks. The water and ash mix in the tanks to form a wet slurry, while the conveying air (with a negligible dust loading) is vented to the atmosphere. The wet slurry drains by gravity to the fly ash pond. Once the fly ash is placed in the active ash pond, it remains wet and is generally submerged under a layer of water. Fugitive dust emissions from fly ash disposal are judged to be negligible.
**Ash Tonnage Estimates:** The maximum potential bottom ash/economizer ash (slag) production was estimated in the Title V permit application based on maximum boiler heat input capacities, minimum heating value for coal, maximum percent ash, & maximum potential operation, using the typical fly ash/bottom ash split for cyclone-fired boilers & the typical split for fly ash capture between the economizer & ESP, as shown below: U 1-3 Maximum boiler heat input capacity, 10^6 Btu/unit-hr = 25375 Minimum heat content for coal, Btu/lb = 1.10E+04 Maximum coal ash content, % = 15 Cyclone boiler fly ash/bottom ash split, % fly ash = 25 Economizer hopper capture of fly ash, % = 10 Potential max. slag production (dry), tons/yr (tpy) = 1.17E+06
**Fugitive Dust Emission Estimates & Controlled Emission Factors (EF):** Fugitive dust emissions due to slag reclaim haul roads, pile maintenance, and wind erosion of open storage areas, were estimated in the Title V permit application (Table 6-2) for these slag handling quantities as:
Loaders hauling slag from pond to dewatering area, tons/yr (tpy) = 2.20E-01 Loaders dumping slag at dewatering area, tpy = 4.62E-02 Slag reclaim loader traffic in dewatering area, tpy = 1.37E-01 Loaders dumping slag in haul trucks, tpy = 6.11E-01 Open storage wind erosion (dewatering area), tpy = 1.14E-01 Haul vehicles--one-way (full) travel departing plant site, tpy = 1.71E+01 Haul vehicles--one-way (empty) return traffic on plant site, tpy = 1.50E+01 Bottom/econ. ash disposal fugitive dust emission total, tpy = 3.32E+01 Bottom/econ. ash disposal fugitive dust EF, lb/dry ton = 5.65E-02
**Title V Total Ash Handling PM Emission Estimate, tpy =** 3.32E+01
**PAF Gypsum Handling***
**Process Description:** Gypsum is formed in the wet flue-gas-desulfurization (FGD) scrubbers of PAF Units 1 and 2 as limestone reacts with sulfur dioxide (SO2). Since the FGD scrubbers also serve as the principal particulate matter (PM) emission control devices for PAF Units 1 and 2, the scrubber effluent slurry contains fly ash as well as gypsum. The gypsum slurry exits the scrubbers via gravity overflow to an effluent slurry tank (one per unit), from which it is pumped to the highest point of the rim ditch system. Rim ditches convey the slurry (pumped at about 15% solids) to 1 of 2 settling ponds (or stacking cells). The rim ditches are constructed from dewatered gypsum already deposited in the stacking area. As a stacking cell is filled, incoming slurry is diverted to the other cell, and the first cell is allowed to dewater. Then a hydraulic trackhoe is used to excavate some of the dewatered gypsum, forming a higher rim-ditch wall to allow for additional sluicing capacity. After the gypsum is excavated, it is spread and formed using a track dozer.

Page 1 of 4

# ash

Side-slope soil cover may be added as needed to the gypsum stack using onsite soil. Pan scrapers are used for soil transport, and a dozer is used to spread the soil cover. Pile capping activities had not yet begun at the time of the Title V permit application, but emissions from these activities were included in the application to cover the possibility of their beginning during this permit cycle. Soil for pile capping will also be obtained onsite.
**Gypsum and Cover Material Tonnage Estimates:** Maximum annual gypsum production was estimated for the Title V permit application using maximum boiler heat input capacity for PAF Units 1-2, maximum SO2 levels in the flue gases entering the FGD scrubbers (5.4 lb/10^6 Btu, based on the SO2 permit limit for PAF Unit 3--at that time all 3 units burned the same compliance coal), nominal maximum scrubber SO2 removal efficiency (88%), continuous annual operation (8760 hr/yr), 5% unreacted limestone (LS) in the gypsum slurry, and an estimated 15% inerts (fly ash + LS inerts) in the gypsum slurry. The maximum annual wet gypsum excavation rate was calculated using the estimated maximum annual gypsum production, the estimated percentage of gypsum production that is used for rim-ditch formation (15%), and the estimated moisture content of the excavated gypsum (50%). Maximum cover material (soil) usage was also estimated. U 1-2 Maximum boiler heat input capacity, 10^6 Btu/unit-hr = 6959 Number of scrubbed units = 2 Maximum SO2 level entering the FGD scrubbers, lb/10^6 Btu = 5.4 Molecular weight of SO2, lb/lb-mole = 64.06 Nominal maximum scrubber SO2 removal efficiency, % = 88 Gypsum (CaSO4.2H2O) : SO2 stoichiometric molar ratio = 1 Molecular weight of CaSO4.2H2O, lb/lb-mole = 172.2 Unreacted LS (CaCO3) in gypsum slurry, % = 5 Molecular weight of CaCO3, lb/lb-mole = 100.1 Estimated inert content of gypsum slurry, % = 15 Maximum annual gypsum production rate (dry), tons/yr (tpy) = 9.43E+05 Estimated fraction of gypsum production used in rim ditch, % = 15 Estimated moisture content of excavated gypsum, % = 50 Maximum annual gypsum excavation rate (wet), tpy = 2.83E+05 Maximum annual soil cover material, cubic yards/yr = 3.70E+04 Soil cover material bulk density, ton/cubic yard = 1.49 Maximum annual soil cover material usage, tpy = 5.51E+04
**Fugitive Dust Emission Estimates & Controlled Emission Factors (EF):** Fugitive dust emissions due to trackhoe excavation, pile maintenance and wind erosion of gypsum open storage areas, along with soil cover material hauling, were estimated in the 12-3-96 Title V permit application (Table 7-2) as follows:
**Gypsum Stacking:** Rim ditch formation--trackhoe excavation, tpy = 2.78E-04 Rim ditch formation--trackhoe movement, tpy = 6.76E-02 Pile maintenance (dozer), tpy = 2.34E-01 Open storage wind erosion, tpy = 9.10E+00 Gypsum stacking fugitive dust emission total, tpy = 9.40E+00 Gypsum stacking fugitive dust EF, lb/dry ton gypsum productn = 1.99E-02
**Cover Material Usage:** Cover matl haul--one-way (full) travel on unpaved roads, tpy = 5.10E-01 Cover material haul--one-way (full) travel over pile, tpy = 3.58E+00 Cover material haul--one-way (empty) travel over pile, tpy = 2.09E+00 Cover matl haul--one-way (empty) travel on unpaved roads, tpy = 2.98E-01 Pile maintenance/capping (dozer), tpy = 1.26E+00 Cover material fugitive dust emission total, tpy = 7.74E+00 Cover material fugitive dust EF, lb/ton = 2.81E-01
**Title V Total Gypsum Handling PM Emission Estimate, tpy =** 1.71E+01
*Reference: Title V Permit Application, Paradise Fossil Plant, 12-3-96.
Note: Due to the de minimis exemption for Toxics Release Inventory (TRI) reporting, trace-element components of fugitivedust emissions from cover-material usage are not considered in TRI estimates. Only trace-element components of byproducthandling (ash, gypsum) PM emissions are considered to be subject to TRI reporting requirements.

Page 2 of 4

# ash

**CY06 PAF By-Product Handling Fugitive-Dust Emission Estimates**
**CY06 PAF By-Product (Ash/Gypsum) Production/Utilization Estimates 

Production, tons/yr (tpy) Notes Fly Ash (U1-2) = 85,916 Fly Ash (U3) = 57,121 Fly Ash Total = 143,037
Bottom Ash/Slag = 429,111 Gypsum (U1-2) = 571,675 Production Subtotal = 1,143,823

Utilization, tpy Fly Ash = 0 Bottom Ash/Slag = 443,285Off-Site Processing for Roofing Granules, Blasting Grit 0On-Site for Road Construction and Repair Bottom Ash/Slag Total = 443,285 Gypsum = 0On-Site Cover material for coal wash refuse 0Off-Site Agricultural Soil Amendment 0 0 Gypsum Total = 0 Utilization Subtotal = 443,285
** Reference: Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al. E.C. Miller confirmed that all production & utilization quantities are dry basis in her 2-28-00 e-mail to J.D. Lokey.
Note: CY06 PAF ash/gypsum production estimates are based on 75% boiler slag/25% fly ash split Gypsum estimates are based on methodology provided by I.J. Berty.
**CY06 PAF By-Product Handling Particulate-Matter (PM)/Fugitive Dust Emission Estimates** PM Emissions, tons/yr (tpy) Notes: PAF Ash-Handling Point Sources = Negligible PAF Bottom Ash/Slag Handling = Negligible PAF Gypsum Handling = 5.70E+00 PAF Bottom Ash/Slag Byproduct Sales = 1.25E+01 PAF Fly Ash Byproduct Disposal = Negligible CY06 PAF By-Product Handling PM Emission Total = 1.82E+01 For sources subject to TRI reporting.
**CY06 PAF By-Product Handling Trace-Element PM/Fugitive-Dust Emission Estimates, tpy*****
PAF Total Byproduct-Handling Point Gypsum Bottom Fly Ash Trace-Element PM/Fugitive Element Sources Handling Ash Sales Disposal Emissions, tpy
Antimony (Sb)

- 8.25E-05 4.29E-05

- 1.25E-04 Arsenic (As)

- 3.87E-04 1.11E-04

- 4.98E-04 Barium (Ba)

- 1.68E-03 1.00E-02

- 1.17E-02 Beryllium (Be)

- 5.00E-05 3.86E-05

- 8.86E-05 Cadmium (Cd)

- 2.94E-05 3.35E-05

- 6.29E-05 Chromium (Cr)

- 3.42E-04 1.15E-03

- 1.49E-03 Cobalt (Co)

- 2.45E-04 7.23E-04

- 9.68E-04 Copper (Cu)

- 3.24E-04 4.91E-04

- 8.15E-04 Lead (Pb)

- 6.18E-04 2.24E-04

- 8.42E-04 Manganese (Mn)

- 4.81E-04 4.28E-03

- 4.76E-03 Mercury (Hg)

- 1.15E-06 3.96E-06

- 5.11E-06 Molybdenum (Mo)

- 3.10E-04 5.32E-04

- 8.42E-04 Nickel (Ni)

- 3.37E-04 1.01E-03

- 1.35E-03 Selenium (Se)

- 5.49E-05 9.94E-05

- 1.54E-04 Silver (Ag)

- 1.79E-06 1.86E-05

- 2.04E-05 Thallium (Tl)

- 6.64E-05 7.61E-05

- 1.42E-04 Vanadium (V)

- 1.05E-03 4.80E-03

- 5.85E-03

Page 3 of 4

# ash

Zinc (Zn)

- 1.56E-03 1.36E-03

- 2.93E-03
***Reference: PISCES Model (ver. 3.11) outputs, obtained from 3-11-02 P31 file on "envshr" drive .
Note: Emission estimates were not included for chloride (Cl) and fluoride (F) since the TRI-reportable form of these elements are the acid gas compounds hydrochloric acid (HCl) aerosol & hydrogen fluoride (HF). The Cl & F anion concentrations estimated for the pyrite, bottom ash, fly ash & gypsum solids streams are believed to exist as neutralized salts of HCl & HF (and therefore are not TRI reportable).
**Polycyclic Aromatic Compounds (PAC) and Hydrocarbons (PAH) in Coal Fly Ash and Bottom Ash******
Pollutant (CAS No.) Coal Fly Ash (mg/kg) Coal Bottom Ash (mg/kg) Frequency Frequency EPCRA PAC of Detection Median Average of Detection Median Average
Benz(a)anthracene (56-55-3) 3/15 1.00E-04 1.95E-04 6/20 7.91E-04 1.42E-03 Benzo(a)phenanthrene (218-01-9)17/30 3.00E-04 7.15E-04 11/24 7.50E-03 7.12E-03 Benzo(a)pyrene (50-32-8) 1/16 2.50E-05 6.57E-05 8/23 1.71E-03 3.55E-03 Benzo(b)fluoranthene (205-99-2) 1/14 4.00E-04 4.00E-04 1/14 1.98E-02 1.88E-02 Benzo(k)fluoranthene (207-08-9) 1/11 5.00E-04 5.00E-04 1/14 2.17E-02 2.15E-02 Dibenz(a,h)anthracene (53-70-3) 1/16 2.50E-05 3.47E-05 8/22 7.67E-04 3.73E-03 Fluoranthene (206-44-0) 21/34 1.80E-03 2.88E-02 12/28 3.39E-03 7.11E-03 Indeno(1,2,3-cd)-pyrene (193-39-5) 2/14 5.86E-03 6.16E-03 6/20 9.26E-04 3.57E-03

Other EPCRA PAH
Anthracene (120-12-7) 5/15 5.00E-04 7.45E-04 5/19 6.86E-04 1.17E-03 Benzo(g,h,i)perylene (191-24-2) 1/16 2.50E-05 6.07E-05 6/21 1.48E-03 1.53E-03 Naphthalene (91-20-3) 30/42 7.10E-02 2.98E-01 21/29 1.80E-02 3.90E-02 Phenanthrene (85-01-8) 25/38 1.30E-02 1.57E-01 15/27 1.10E-02 1.52E-02
 Reference: 5-29-01 e-mail from N. Goodman (EPRI) to J.D. Lokey. [Data obtained from EPRI's PISCES Database, Individual Data Points for Trace Components in Combustion Byproducts-- All coal types, all USGS provinces, all boiler types, excluding poor or unknown quality data; concentrations are dry basis]
Non-detect concentrations are set = to 0.5 x detection limit (DL), excluding samples where DL are > 2 x the highest quantified value.
No data are available for PAC/PAH concentrations in gypsum byproducts.
** CY05 PAF 1-3 Ash-Handling PAC/PAH PM/Fugitive-Dust Emission Estimates, tpy*****
PAF Total Ash-Handling Point Bottom Fly Ash PAC/PAH PM/Fugitive Pollutant (CAS No.) Sources Ash Sales Disposal Emissions, tpy

EPCRA PAC
Benz(a)anthracene (56-55-3)

- 9.90E-09

- 9.90E-09 Benzo(a)phenanthrene (218-01-9)

- 9.39E-08

- 9.39E-08 Benzo(a)pyrene (50-32-8)

- 2.14E-08

- 2.14E-08 Benzo(b)fluoranthene (205-99-2)

- 2.47E-07

- 2.47E-07 Benzo(k)fluoranthene (207-08-9)

- 2.72E-07

- 2.72E-07 Dibenz(a,h)anthracene (53-70-3)

- 9.60E-09

- 9.60E-09 Fluoranthene (206-44-0)

- 4.24E-08

- 4.24E-08 Indeno(1,2,3-cd)-pyrene (193-39-5)

- 1.16E-08

- 1.16E-08

Other EPCRA PAH
Anthracene (120-12-7)

- 8.58E-09

- 8.58E-09 Benzo(g,h,i)perylene (191-24-2)

- 1.85E-08

- 1.85E-08 Naphthalene (91-20-3)

- 2.25E-07

- 2.25E-07 Phenanthrene (85-01-8)

- 1.38E-07

- 1.38E-07 TVA Air, Land & Water Sciences 03/26/07

Page 4 of 4

### NH3

**Data Elements Needed Input value**  Plant Configuration **APH, Wet FGD, No FGC** PAF Unit 1 PAF Unit 2 PAF Units 1-2 Total coal burn (tons/yr):(4) 

### 1,994,961 1,784,432 3,779,393 Total boiler use (hr/yr):(4) 

### 8,029 7,263 15,293 **Flue gas flow by CEMS or by amount of coal burned** (2) 

### Hours of SCR NH3 feed (hr/yr):(5) 

### 3,300 3,138 6,438 CY06 SCR operating factor (w/ NH3 feed): 0.411 0.432 0.421 Coal burn (tons/yr with NH3 feed) ILB 1,548,887 Coal burn during SCR NH3 feed (tons/yr): 819,921 770,917 1,590,838 ILB Coal Fines 30,496

PRB 25,681 Region PAF Unit 1 PAF Unit 2 PAF Units 1-2 Coal heating value (Btu/lb)(3) 

### ILB 11,756 ILB 1,942,353 1,737,376 3,679,729 ILB Coal Fines 6,673 ILB Fines 38,243 34,208 72,451

PRB 8,851 PRB 32,205 28,806 61,011 Total 2,012,801 1,800,390 3,813,191 **NOx Reduction Ammonia Slip** Dry Basis Average ammonia slip (ppmv wet basis)(6) 

### 1.838346 2ppmvd(6)

### at 3 Region PAF Unit 1 PAF Unit 2 PAF Units 1-2 Operating factor for SCR/SNCR (fraction)(7) 

### 1 ILB 798,299 750,588 1,548,887 ILB Fines 15,718 14,778 30,496 **FGC Ammonia Injection** PRB 13,236 12,445 25,681 Total 827,253 777,812 1,605,064
**Fly Ash Sales Factor (decimal fraction) (8)**  

### 0 NH3 rcvd lbs 0(truck) Truck-unloading NH3 emission factor = 1.38E-05lb/lb of recpts **Fugitive losses from tank farm (9)**  

### 1.9 18,564,920(rail) Railcar-unloading NH3 emission factor = 1.05E-07lb/lb of recpts

**Ammonia in boiler w ater treatment (lbs)** **(10)** 

### 5,359 47,260lbs of aqua ammonia, assumed to be 35% ammonium hydroxide (NH4OH) Boiler water discharge (open tank or ash pond) Ash Pond

Notes: (1)

### Ammonia RY2005 Release Calculator model (v0.3) based on "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," by S.L. Wilson, K.E. Harrison, & L.S. Monroe. (2)

### The model estimates flue-gas flow from coal-burn quantity using bituminous coal-fired wet flue-gas F factor at 3% O2 (12,423 wet std. ft^3/MBtu) (3)

### Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. in CY 06\Release Estimates\Coal and Limestone folder on FPG Env Affr - TRI ("chapgfs5") server. (4)

### Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server. (5)

### SCR hours with ammonia feed listed in 1-25-07 e-mail from R.L. Beasley to K.J. Dukes et al., archived in CY 06\Completed Questionnaire\PAF folder on FPG Env Affr - TRI ("chapgfs5") server. (6)

### TRI team decided to use vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours, per 1-11-01 conversation with R.A. Babb, unless recent flue-gas measurements are available. To convert dry-basis flue-gas concentration to wet-basis, multiply by ratio of bituminous coal-fired F-factors at 0% O2: 9,780/10,640 (dry std. ft^3/MBtu)/(wet std. ft^3/MBtu). O2 content or total air in flue gas where slip was measured must be considered to estimate mass emissions from ammonia slip concentration. Since the NH3 estimator model requires NH3 concentration expressed at 3% O2, adjust the measured NH3 value from measured O2 level to 3% O2 by multiplying by (20.9-3)/(20.9-measured %O2). (7)

### Since the coal burn has been adjusted for the hours of SCR operation, the operating factor is 1.0 (8)

### No CY06 PAF fly-ash sales, per Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al., archived in the CY 06\Release Estimates\Ash Data folder. (9)

### Anhydrous ammonia receipts/usage listed in 1-25-07 e-mail from R.L. Beasley to K.J. Dukes et al., archived in CY 06\Completed Questionnaire\PAF folder on FPG Env Affr - TRI ("chapgfs5") server. The first model run for PAF Units 1 and 2 fully accounts for plant-total fugitives from tank-farm operation. (10)

### Aqua NH3 usage listed in 1-25-07 e-mail from K.J. Dukes to J.D. Lokey et al., archived in CY06\Completed Questionnaire\PAF folder on FPG Env Affr - TRI ("chapgfs5") server. Unless otherwise indicated, BWT NH3 usage estimated at aqua NH4OH concentratn = 35weight %. Aqua usage was split equally among the three units.

PAF U1-2 NH3 PAF NH3 Stack Emissions, lb/yr Species Type of Release ILB ILB Fines PRB Total Contrl Effcncy, % PAF 1 PAF 2 NH3 SCR-exit 36,741 411 459 37,610 NH3 Stack 0.367 0.004 3.44 3.81 99.99 1.96 1.85 Ammonium salts(1) 

### Stack 1,532 17.1 5.10 1,554 NH3 Fugitive 6,110 62.3 408 6,580

Notes:

(1)

### Stack releases of ammonium salts such as ammonium bisulfate (ABS) and ammonium sulfate (AS), expressed as NH3-equivalent mass rates, are emitted in the particulate-matter (PM) phase. They are subsumed within stack PM emissions for emission-inventory purposes, and also are not reportable for Toxics Release Inventory (TRI) purposes.

TVA Environmental Technologies 03/26/07 **Table 1. Input Data for CY06 PAF Units 1-2 Ammonia (NH3) Emission-Estimation Model (1)** 



### Table 2. Summary of CY06 PAF Units 1-2 Ammonia (NH3) & Ammonium-Salt Air Emission Estimates

Coal Region CY06 PAF Units 1-2 Operating Statistics Coal-Burn & Boiler/SCR Data:

CY06 PAF Units 1-2 Coal Burn by Supply Region, tons/yr(3)



### CY06 PAF Units 1-2 Coal burned during NH3 feed, tons/yr

PAF Units 1-2 NH3/ABS Air Emissions, lb/yr

Page 1 of 1

## H2SO4

**CY06 Paradise Fossil Plant (PAF) Sulfuric Acid (H2SO4) Manufacture/Emission Estimates**
Sulfuric acid (H2SO4) is created in the ductwork downstream of coal-fired boilers by the combination of water vapor and sulfur trioxide (SO3). Most of the coal sulfur is released during combustion as sulfur dioxide (SO2), but a portion is further oxidized to form SO3. A paper by Hardman, Stacy, & Dismukes [HSD] as revised(1)

## is incorporated in EPRI's Lark-Tripp (LT) emission-estimation model that is used by many electric utilities for Toxics Release Inventory (TRI) reporting. The HSD study indicates that for a given boiler type (e.g., cyclone-fired) and coal type (e.g., Eastern bituminous), the SO3:SO2 molar ratio can be considered constant. Data in the HSD paper (see "Inputs" worksheet) indicate that cyclone-fired boiler-exit SO3 concentrations are 1.6% of the SO2 concentrations for Eastern bituminous coals, and 0.18% for Powder River Basin (PRB) subbituminous coal. The PAF boilers are cyclone-fired. In CY06, PAF Units 1-2 burned nearly 100% Illinois Basin (ILB) Eastern bituminous coal/coal fines, but CY06 PAF Unit 3 heat inputs consisted of 50.1% ILB coal/coal fines and 49.9% PRB subbituminous coal. PAF Units 1-3 flue-gas measurements(2)

## have indicated that boiler-exit SO3/H2SO4 flue-gas concentrations produced when burning 100% ILB coal are about 40parts per million by volume dry-basis (ppmvd) at 3% flue-gas oxygen (O2) concentration, whereas burning an equal mix of ILB and PRB coals in PAF Unit 3 produced about 5ppmvd boiler-exit SO3/H2SO4 concentrations.
At high proportions of low-sulfur PRB coal burned in PAF Unit 3, SO3 concentrations may be too low for proper operation of the electrostatic precipitator (ESP), the particulate-matter (PM) emission control system for PAF 3. Molten sulfur (S) may be burned ina flue-gas conditioning (FGC) system, producing SO3 for injection into the boiler flue gas downstream of the air heater (AH). At flue-gas temperatures prevailing at & downstream of the AH, essentially all the SO3 combines with water vapor to form H2SO4. SO3/H2SO4 adsorb onto & react with fly ash particles, decreasing their resistivity so as to enhance PM removal efficiency in the ESP. No molten S was burned in the FGC system during CY06; the system is no longer in use.(3)



## Table 1. CY06 PAF Flue-Gas-Conditioning (FGC) SO3/H2SO4 Manufacture Estimates
CY06 PAF molten-S receipts 0pounds Molten-S tank capacity = 50tons CY06 PAF molten S burned 0.00tons FGC SO3/H2SO4 production 0tons H2SO4 equivalent/yr (based on sulfur receipts)
Boiler-produced and other SO3/H2SO4 concentrations can be reduced by PM-control devices (e.g., ESP), SO2 removal systems (e.g., flue-gas desulfurization (FGD) scrubbers), and other equipment (e.g., air heaters). Some H2SO4 condenses on AH surfaces where it may react with the metal to form salts, and some adsorbs onto & reacts with flue-gas fly-ash particles. Similarly, H2SO4 collected along with the ash in a cold-side ESP or bagfilter may react with the ash to form salts. Scrubbers will typically neutralize all of the H2SO4 captured. H2SO4 captured in air heaters and emission control equipment was considered to be neutralized by reaction with metal surfaces or alkaline components of the ash or scrubber slurry and will not be reported as a TRI release. Nominal H2SO4 control efficiencies in these equipment (as listed in the HSD study) were used to estimate CY06 PAF SO3/H2SO4 emissions. An FGD scrubber began operation on PAF Unit 3 in October 2006, so CY06 Unit 3 region-specific coal burn was apportioned between pre- and post-FGD operations.

**Table 2. CY06 PAF Coal-fired Region-Specific Boiler Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**

COAL REGION: IL Basin (ILB) coal BOILER/COAL TYPE:CYCL/HSE SO3/SO2 MOLAR RATIO (%): 1.6

Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Coal Burned, tons/year 1,942,353 1,737,376 3,679,729 738,759 580,235 1,318,994 4,998,723 Coal Heating Value, As Received (Btu/lb) 11,756 11,756 11,756 11,756 Sulfur Content, % 2.78 2.78 2.78 2.78 Coal Sulfur Conversion to Sulfur Oxides (SOx), % 95 95 95 95 Coal-fired Heat Inputs, 10^12 Btu/yr 45.67 40.85 86.52 17.37 13.64 31.01 117.53 Boiler-Exit SOx expressed as SO2, tons/yr 102,491 91,675 194,166 38,982 30,617 69,598 263,764 Boiler-Exit SOx converted to SO3, % 1.60 1.60 1.60 1.60 Boiler SO3/H2SO4 Production, tons H2SO4/yr 2,511 2,246 4,756 955 750 1,705 6,461 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP AH/HSE+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 69.2 49.8 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 1387 1241 2,628 625 231 856 3,483

COAL REGION: ILB coal fines BOILER/COAL TYPE:CYCL/HSE SO3/SO2 MOLAR RATIO (%): 1.6

Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Coal Burned, tons/year 38,243 34,208 72,451 29,054 31,188 60,242 132,693 Coal Heating Value, As Received (Btu/lb) 6,673 6,673 6,673 6,673 Sulfur Content, % 3.06 3.06 3.06 3.06 Coal Sulfur Conversion to Sulfur Oxides (SOx), % 95 95 95 95 Coal-fired Heat Inputs, 10^12 Btu/yr 0.51 0.46 0.97 0.39 0.42 0.80 1.77 Boiler-Exit SOx expressed as SO2, tons/yr 2,221 1,987 4,208 1,687 1,811 3,499 7,707 Boiler-Exit SOx converted to SO3, % 1.60 1.60 1.60 1.60 Boiler SO3/H2SO4 Production, tons H2SO4/yr 54.4 48.7 103 41.3 44.4 85.7 189 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP AH/HSE+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 69.2 52.5 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 30.1 26.9 56.9 27.1 13.6 40.7 97.7

COAL REGION: PRB Subbituminous coal BOILER/COAL TYPE:CYCL/PRB SO3/SO2 MOLAR RATIO (%): 0.18

Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Coal Burned, tons/year 32,205 28,806 61,011 1,791,422 0 1,791,422 1,852,433 Coal Heating Value, As Received (Btu/lb) 8,851 8,851 8,851 8,851 Sulfur Content, % 0.29 0.29 0.29 0.29 Coal Sulfur Conversion to Sulfur Oxides (SOx), % 87.5 87.5 87.5 87.5 Coal-fired Heat Inputs, 10^12 Btu/yr 0.57 0.51 1.08 31.71 0.00 31.71 32.79 Boiler-Exit SOx expressed as SO2, tons/yr 163 146 309 9,082 0 9,082 9,392 Boiler-Exit SOx converted to SO3, % 0.180 0.180 0.180 0.180 Boiler SO3/H2SO4 Production, tons H2SO4/yr 0.450 0.402 0.852 25.0 0.0 25.0 25.9 Air Pollution Control System(s): AH/W+WV AH/W+WV AH/W+ESP AH/W+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 63.6 63.6 59.1 83.6 59.1 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 0.164 0.146 0.310 10.2 0.0 10.2 10.5

Page 1 of 4

## H2SO4

**Table 3. CY06 PAF Coal-Fired Boiler-Total Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**

Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Coal-Total Heat Inputs, 10^12 Btu/yr 46.75 41.82 88.56 49.47 14.06 63.53 152.09 Boiler-Exit SOx expressed as SO2, tons/yr 104,875 93,808 198,683 49,751 32,428 82,180 280,863 Boiler SO3/H2SO4 Production, tons H2SO4/yr 2,565 2,295 4,860 1,021 794 1,816 6,676 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 1,417 1,268 2,685 662 244 907 3,592 SO3/H2SO4 Control Efficiency, % 44.8 44.8 44.8 35.2 69.2 50.1 46.2 Blr contrib. to SO3/H2SO4 stk concen (ppmvd at 3% O2) 20.9 20.9 20.9 9.2 12.0 9.8 16.3
**Production & Emission Estimates for SO3/H2SO4 Derived from PAF Selective-Catalytic-Reduction (SCR) Reactors**
Ammonia (NH3)-based selective-catalytic-reduction (SCR) reactors for nitrogen oxides (NOx) control have been installed on PAF Units 1-3 beginning inCY00. A side reaction in the SCR catalyst produces additional SO3, with design oxidation rates(4)

## of 0.75% of SO2 input to the SCR being converted to SO3. CY06 SO3/H2SO4 emission inventory was estimated based on total CY06 SCR in-service hours (with & without NH3 inputs),(5)

## but BART (maximum short-term) emissions were estimated using 1.0 for the total SCR operation factor (i.e., the coal-burn fraction with SCR reactors in the flue-gas path).
An additional complexity related to the SCR operation is the gas-phase reaction between NH3 inputs and excess flue-gas SO3/H2SO4. Wilson et al.(6)

## indicate that NH3, an alkaline chemical, is quite reactive with SO3/H2SO4 at flue-gas conditions existing at and downstream of the AH (temperatures 257 deg F and cooler). NH3 slip (NH3 escaping the SCR catalytic chamber) will neutralize some of the flue-gas SO3/H2SO4 to form ammonium salts. Ammonium bisulfate (NH4HSO4) is expected to be the predominant product when SO3 is present in excess of NH3 concentrations, whereas ammonium sulfate ([NH4]2SO4) is expected to predominate when NH3 is more than double the SO3 concentration. The vendor-guaranteed maximum SCR-exit NH3 slip (at 20,000 hours SCR operation) is 2ppmv dry basis.(7)

## As noted in Table 7, overall PAF SCR-exit (AH-inlet) flue-gas SO3/H2SO4 concentrations are predicted to exceed maximum NH3 levels. Reaction with NH3 slip should proceed very nearly to completion, consuming essentially all the NH3 slip to form NH4HSO4 solid particles that will be effectively captured by the PM control systems. EPRI's recent revision of the HSD paper(1)

## added an alkaline-ash adjustment factor (F3_SCR) for SO2 oxidation by SCR reactors in boilers burning PRB subbituminous coal. Maximum NH3 slip at PAF is higher than SCR-exit SO3 concentrations expected when burning PRB coal alone, so the methodology predicts negative PRB-fired SCR contributions to stack-exit SO3 emissions. This means that excess NH3 reacts with SCR-exit SO3 produced from other coals in the PAF boiler blend. The contribution of SCR reactors to PAF SO3/H2SO4 emissions was estimated (per HSD study) as:

SCR releases = (production - NH3 neutralization)*(1 - control efficiency/100)
**Table 4. CY06 PAF Coal-fired Region-Specific SCR-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**

COAL REGION: IL Basin (ILB) coal Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3
Boiler-Exit SOx expressed as SO2, tons/yr 102,491 91,675 194,166 38,982 30,617 69,598 263,764 SCR total (w/ & w/o NH3) in-service hours 3,308 3,231 3,338 0 Boiler in-service hours 8,029 7,263 5,289 1,473 6,762 SCR operation factor (total) 1.000 1.000 1.000 1.000 SCR SO3/H2SO4 production, tons H2SO4/yr 1177 1053 2,229 448 352 799 3,029 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP AH/HSE+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 69.2 SCR-outlet NH3 Slip (ppmvd at 3% O2) 2 2 2 2 SCR in-service hours (with NH3) 3,300 3,138 3,304 0 SCR operation factor (with NH3) 0.411 0.432 0.625 0.000 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 620 553 1,173 272 108 380 1,554

COAL REGION: ILB coal fines Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3
Boiler-Exit SOx expressed as SO2, tons/yr 2,221 1,987 4,208 1,687 1,811 3,499 7,707 SCR total (w/ & w/o NH3) in-service hours 3,308 3,231 3,338 0 Boiler in-service hours 8,029 7,263 5,289 1,473 6,762 SCR operation factor (total) 1.000 1.000 1.000 1.000 SCR SO3/H2SO4 production, tons H2SO4/yr 25.5 22.8 48.3 19.4 20.8 40.2 88.5 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP AH/HSE+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 69.2 SCR-outlet NH3 Slip (ppmvd at 3% O2) 2 2 2 2 SCR in-service hours (with NH3) 3,300 3,138 3,304 0 SCR operation factor (with NH3) 0.411 0.432 0.625 0.000 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 13.8 12.3 26 12.2 6.40 18.6 44.7

COAL REGION: PRB Subbituminous coal Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3
Boiler-Exit SOx expressed as SO2, tons/yr 163 146 309 9,082 0 9,082 9,392 SCR total (w/ & w/o NH3) in-service hours 3,308 3,231 3,338 0 Boiler in-service hours 8,029 7,263 5,289 1,473 6,762 SCR operation factor (total) 1.000 1.000 1.000 1.000 SCR SO3/H2SO4 production, tons H2SO4/yr 0.319 0.285 0.60 17.7 0.0 18 18.3 Air Pollution Control System(s): AH/W+WV AH/W+WV AH/W+ESP AH/W+ESP+WST Overall SO3/H2SO4 Control Efficiency, % 63.6 63.6 59.1 83.6 SCR-outlet NH3 Slip (ppmvd at 3% O2) 2 2 2 2 SCR in-service hours (with NH3) 3,300 3,138 3,304 0 SCR operation factor (with NH3) 0.411 0.432 0.625 0.000 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr -0.132 -0.129 -0.261 -16.3 0 -16.3 -16.6
**Table 5. CY06 PAF Coal-Fired Boiler-Total SCR-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**

Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3
Coal-Total Heat Inputs, 10^12 Btu/yr 46.75 41.82 88.56 49.47 14.06 63.53 152.09 Total-Coal SCR SO3/H2SO4 Production, tons H2SO4/yr 1203 1076 2,278 485 372 857 3,135 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 634 565 1,199 268 115 383 1,582 SO3/H2SO4 Control Efficiency, % 47.3 47.4 47.4 44.7 69.2 55.3 49.5 SCR contrib. to SO3/H2SO4 stk concen (ppmvd at 3% O2) 9.3 9.3 9.3 3.7 5.6 4.2 7.2

Page 2 of 4

## H2SO4

**Production & Emission Estimates for SO3/H2SO4 Derived from PAF Unit 3 Flue-Gas Conditioning (FGC) System**
The HSD method for estimating SO3/H2SO4 manufactured by FGC systems is based on expected SO3 flue-gas concentrations and an FGC operating factor (fraction of coal burn when FGC system operates). The default SO3 concentration for FGC systems with injection after the APH is 5 ppmv, but 10 ppmv is the operational concentration for the PAF Unit 3 FGC system.(8)

## The FGC system has not been operated since CY02. The CY02 coal-burn fraction during FGC system operation was estimated by setting the quantity of FGC SO3/H2SO4 manufacture (as predicted by the HSD method) equal to the amount of H2SO4 predicted to result from burning CY02 sulfur (S) receipts.
The HSD paper indicates that release of SO3/H2SO4 manufactured in FGC systems varies according to coal type and SO3 injection location. The PAF Unit 3 FGC system SO3 injection point is downstream of the air heaters (AH).(8)

## HSD control efficiencies are:
ESP FGC SO3/H2SO4 removal for injection dnstrm of AH = 90% for E. bitum. coal & 98% for W. bitum & subitum coals.
**Table 6. CY06 PAF Flue-Gas-Conditioning (FGC) SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**

CY06 Parameters: PAF 3 Coal Region ILB coal ILB coal fines PRB All Coals Coal Burn, ton/yr (as received) 1,318,994 60,242 1,791,422 3,170,658 Heat Value, Btu/lb (as received) 11,756 6,673 8,851 FGC System Operating Factor, % 0.00 0.00 0.00 Based on CY06 S receipts. SO3 Injection Rate, ppmv at 6% O2 10 10 10 FGC SO3/H2SO4 production, tons H2SO4/yr 0 0 0 0 SO3/H2SO4 release due to FGC operatn, tons/yr 0.0 0.0 0.0 0.0
**Table 7. CY06 Estimates of Coal-fired SO3/H2SO4 Manufactured in PAF Boilers + FGC & SCR Production (HSD Method)**

AH-Inlet SO3/H2SO4 Flue-Gas Concentrations & Mass Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 SO3/H2SO4 Production Rate, tons H2SO4/yr 3,768 3,370 7,138 1,506 1,167 2,673 9,811 AH-inlet SO3/H2SO4 Concentration (ppmvd at 3% O2) 55.6 55.6 55.6 21.0 57.2 29.0 44.5

**Table 8. CY06 PAF Coal-fired SO3/H2SO4 Emission Estimates (HSD Method)**

Stack-Exit SO3/H2SO4 Flue-Gas Concentrations & Emission Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 2,051 1,833 3,884 930 359 1,289 5,173 Overall SO3/H2SO4 Control Efficiency, % 45.6 45.6 45.6 38.2 69.2 51.8 47.3 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 30.3 30.2 30.2 13.0 17.6 14.0 23.5

A test campaign(9)

## was conducted on PAF Unit 2 in March 2005 to evaluate SO3-mitigation measures such as hydrated-lime injection for opacity reduction. Stack-exit SO3/H2SO4 flue-gas measurements averaged 17.7ppmvd at 3% O2 under baseline conditions (burning 100% ILB coal, with in-service but no SO3 mitigation). Stack-exit SO3/H2SO4 flue-gas measurements while burning ILB coal with sulfur content typical of CY05 coal burn, but with SCR reactors bypassed and no lime injection, were reported as 14.2ppmvd at 3% O2. This value closely matches PAF Units 1-2 ILB stack-exit SO3/H2SO4 flue-gas measurements(2)

## prior to SCR installation,about 13ppmvd at 3% O2.
TVA considers these limited SO3/H2SO4 stack data, although less than those predicted by the HSD method (Table 8), to be reasonably representative of CY06 PAF Units 1-2 emissions, and used the test data for those units' TRI and emission-inventory estimates. Baseline CY06 PAF Units 1-2 SO3/H2SO4 emission estimates given in Table 9 reflect BART (maximum short-term) stack-exit flue-gas concentrations when burning IL Basin coal with in-service SCR reactors and no SO3 mitigation. PAF Unit 3 emission estimates in Table 9 reflect HSD-method predictions for CY06 pre- and post-FGD operations with in-service SCR reactors. CY06 pre-FGD coal burn was 70% PRB/30% ILB , whereas post-FGD coal burn was 100% ILB.
No AH-inlet SO3/H2SO4 flue-gas measurements were made in the March 2005 campaign. AH-outlet flue-gas concentrations were measured, but these data are not considered representative for predicting SO3/H2SO4 manufacture in PAF boilers and SCR reactors. Due to relatively low AH-outlet temperatures (duct averages ranged from 280 - 309 degrees F), an unquantified extent of SO3/H2SO4 reduction may be expected to occur across the AH. TVA believes that the HSD-method predictions in Table 7 are realistic values for AH-inlet mass rates and flue-gas concentrations, and has used those values to estimate PAF boiler and SCR-reactor SO3/H2SO4 manufacture and treatment quantities for TRI/emission-inventory reporting.

**Table 9. Baseline CY06 PAF Coal-fired SO3/H2SO4 Emission Estimates (Flue-gas-concentration Method for PAF Units 1-2, HSD Method for PAF Unit 3)**

Stack-Exit SO3/H2SO4 Flue-Gas Concentrations & Emission Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 17.7 17.7 17.7 13.0 17.6 14.0 16.2 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 1,202 1,075 2,277 930 359 1,289 3,566 SO3/H2SO4 Removal (Treatment), tons H2SO4/yr 2,566 2,296 4,862 575 808 1,383 6,245 Overall SO3/H2SO4 Control Efficiency, % 68.1 68.1 68.1 38.2 69.2 51.8 63.7
TVA is considering two options for BART-control evaluation: hydrated-lime injection and wet-ESP installation. Hydrated-lime injection will not reduce filterable PM emissions, but is expected to reduce stack-exit SO3/H2SO4 concentrations to 7ppmvd at 3%O2.(10)

## Wet ESP controls are expected to reduce baseline SO3/H2SO4 concentrations by 90%to 1.8ppmvd at 3%O2, and should achieve 0.015lb/10^6 Btu filterable-PM emissions, the level of control required by New Source Performance Standards (NSPS).(10)

## Some concerns exist as to whether a retrofit wet ESP would be able to achieve this level of control, so TVA decided also to evaluate a wet ESP achieving 0.030lb/10^6 Btu filterable-PM emissions. SO3/H2SO4 emission estimates for these scenarios are presented in Tables 10-11.
**Table 10. CY06 PAF Coal-fired SO3/H2SO4 & Filterable-PM10 Emission Estimates for Hydrated-Lime-Injection Control Scenario**

Stack-Exit SO3/H2SO4 Flue-Gas Concentrations & Emission Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 7.0 7.0 7.0 7.0 7.0 7.0 7.0 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 475 424 899 502 143 645 1,544 Overall SO3/H2SO4 Control Efficiency, % 87.4 87.4 87.4 66.7 87.8 75.9 84.3 SO3/H2SO4 Stack Emissions, lb H2SO4/hr 141 141 283 233 233 233 515 Filterable-PM10 Stack Emissions, lb PM10_fil/hr 502 519 1,021 296 296 296 1,317

Page 3 of 4

## H2SO4

**Table 11. CY06 PAF Coal-fired SO3/H2SO4 & Filterable-PM10 Emission Estimates for Wet-ESP Control Scenarios**

Stack-Exit SO3/H2SO4 Flue-Gas Concentrations & Emission Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF 3 pre-FGD PAF 3 post-FGD PAF 3 Total PAF 1-3 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 1.8 1.8 1.8 1.8 1.8 1.8 1.8 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 122 109 231 129 37 166 397 Overall SO3/H2SO4 Control Efficiency, % 96.8 96.8 96.8 91.4 96.9 93.8 96.0 SO3/H2SO4 Stack Emissions, lb H2SO4/hr 36.3 36.3 72.7 59.8 59.8 59.8 132 Filterable-PM10 Stack Emissions, lb PM10_fil/hr at 0.015lb/10^6 Btu 71.0 71.0 142 117 117 117 259 Filterable-PM10 Stack Emissions, lb PM10_fil/hr at 0.030lb/10^6 Btu 142 142 284 234 234 234 518

Notes:

(1)

## "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, & Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, 3-98; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); and by L.S. Monroe, 5-01, and by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.

(2)

## Per 4-27-99 personal communication between G.T. Munson and J.D. Lokey.

(3)

## Per 1-24-07 e-mail from K.J. Dukes to J.D. Lokey et al., molten sulfur is no longer used at PAF.

(4)

## Per 3-19-03 e-mail from R.A. Babb to S.S. Koss et al., confirmed in 2-15-05 e-mail from J.D. Giles to C.M. Anderson.

(5)

## SCR hours with ammonia feed listed in 1-25-07 e-mail from R.L. Beasley to K.J. Dukes et al., archived in CY 06\Completed Questionnaire\PAF folder.

(6)

## S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05.

(7)

## Per 1-11-01 conversation with R.A. Babb regarding vendor-guaranteed maximum SCR-exit NH3 slip at 20,000 hours SCR operation.

(8)

## Per 4-18-03 phone conversation between J.H. Lytle and J.D. Lokey.

(9)

## Word file "PAF U2 Opacity Reduction Testing Final Report1.doc," 4-8-05, authored by M.A. Thompson, downloaded 5-25-05 from TVA Fossil Power Group (FPG) Air, Gas, Water, & Yard (AGWY) Systems' SO3 Mitigation website (TVA Intranet).

(10)

## Excel file "PAF BART emissions for modeling comments.xls" in 3-19-07 e-mail from J.D. Giles to J.T. Waddell et al. TVA Environmental Technologies 03/26/07

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## welding



# Table 1. Paradise Fossil Plant (PA**F) - CY05 Welding Rod Emissions**

**Type Description**  **Emission Factor 1,2**  

## Emissions (lbs) **Allied FGD**  **Total Cr**  **Co Mn**  **Ni Pb**  **PM 10**  

## Cr **Co Mn**  **Ni Pb**  **PM 10**  

## 14Mn- 4Cr 0 0 0 13.9 ND 232 17.1 ND 81.6 0.00 0.00 0.00 0.0 AVERAGE 2,966 5,262 8,228 3.46 0.01 15.68 2.72 0.93 18.37 2.85 0.01 12.90 2.24 0.77 151.1 E110 0 0 0 0.02 ND 20.2 1.12 ND 20.8 0.00 0.00 0.00 0.0 E11018 0 0 0 9.69 ND 13.8 1.02 ND 57.0 0.00 0.00 0.00 0.0 E308 456 414 870 5.24 0.01 3.46 1.84 ND 10.8 0.46 0.00 0.30 0.16 9.4 E310 30 0 30 25.3 ND 22 1.96 0.24 15.1 0.08 0.07 0.01 0.00 0.5 E316 36 0 36 9.7 ND 5.9 0.93 ND 10.0 0.03 0.02 0.00 0.4 E410 10 0 10 ND ND 6.85 0.14 ND 13.2 0.01 0.00 0.1 E6010 2,150 0 2,150 0.03 ND 9.91 0.04 ND 25.6 0.01 2.13 0.01 55.0 E6011 0 0 0 0.05 0.01 9.98 0.05 ND 38.4 0.00 0.00 0.00 0.00 0.0 E6012 0 0 0 ND ND ND ND ND 8.0 0.0 E6013 10 0 10 0.04 0.01 9.45 0.02 ND 19.7 0.00 0.00 0.01 0.00 0.2 E7018 9,660 1,068 10,728 0.06 0.01 10.3 0.02 ND 18.4 0.06 0.01 11.05 0.02 197.4 E7024 200 0 200 0.01 ND 6.29 ND ND 9.2 0.00 0.13 1.8 E7028 0 0 0 0.13 ND 8.46 ND 1.62 18.0 0.00 0.00 0.00 0.0 E70S 0 0 0 0.01 0.01 3.18 0.01 ND 5.2 0.00 0.00 0.00 0.00 0.0 E70T 0 0 0 0.04 ND 8.91 0.05 ND 15.1 0.00 0.00 0.00 0.0 E71T 0 0 0 0.02 0.02 6.62 0.04 ND 12.2 0.00 0.00 0.00 0.00 0.0 E8018 1,240 0 1,240 0.17 ND 0.3 0.51 ND 17.1 0.02 0.04 0.06 21.2 E9015 0 0 0 ND ND ND ND ND 17.0 0.0 E9018 220 0 220 2.12 ND 7.83 0.13 ND 16.9 0.05 0.17 0.00 3.7 ECoCr 0 0 0 ND ND ND ND ND 27.9 0.0 EM12K 0 0 0 ND ND ND ND ND 0.05 0.0 ENi-Cl 0 0 0 ND ND 0.39 8.9 ND 18.2 0.00 0.00 0.0 ENiCrMo 0 104 104 4.2 ND 0.43 2.47 ND 11.7 0.04 0.00 0.03 1.2 ENi-Cu 0 0 0 ND ND ND ND ND 10.1 0.0 **Welding Rod Usage (lbs) 3** 



## ENi-Cu 0 0 0 ND ND ND ND ND 10.1 0.0 ENi-Cu-2 0 0 0 ND ND 2.12 4.23 ND ND 0.00 0.00 ER1260 0 0 0 0.04 ND ND ND ND 20.5 0.00 0.0 ER316 0 0 0 5.28 ND 2.45 2.26 ND 3.2 0.00 0.00 0.00 0.0 ER5154 0 0 0 0.1 ND 0.34 ND ND 24.1 0.00 0.00 0.0 ERNiCrMo 0 0 0 3.53 ND 0.7 12.5 ND 3.9 0.00 0.00 0.00 0.0 ERNiCu 0 0 0 0.01 ND 0.22 4.51 ND 2.0 0.00 0.00 0.00 0.0 **Total 16,978**  **6,848 23,826** 

**-- --**  **-- --**  **-- --**  **3.60 0.02**  **26.83 2.53**  **0.77 442.1** 

Notes:

**1**

## Emission Factors: Pounds (lb) of metal (trace-element hazardous air pollutant [HAP]) emitted per 10,000 lb of welding rods used, or lb of particulate-matter < 10 micrometers (PM-10) per 1000 lb of welding rods used (from AP-42, 5th Edition, Section 12.19 Electric Arc Welding, 1/95, Table 12.19-1 and 19-2, selecting the highest emission factor for a given electrode where multiple welding processes are listed). **2**

## NDdenotes "No Data." **3**

## CY05 PAF welding-rod consumption data taken from Excel file "Fossil Fugitive Air Emissions CY05.xls" posted 4-26-06 in FPG Env Affr - TRI folder on "Chapgfs5" server.

Welding-rod emissions were not subsumed in PAF plant-total fugitive air emissions, but are included in this file to document that emissions from PAF welding activities are negligible.
TVA Environmental Technologies 03/26/07

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PARADISE FOSSIL PLANT BOILERS + FUGITIVE SOURCES CY06 AIR EMISSION ESTIMATES DATE: 03/26/07 (TONS/YEAR) BASED ON:

CY06 FUEL & CEMS DATA(1) Paradise Fossil Plant (PAF) Air Emission Estimates, tons/year REGION-SPECIFIC TRACE ELEM(2) MEDIAN EFH HAP EMISSN FACTORS(3) Unit 1 Unit 2 Unit 3 Boiler Total Other Sources & Plant Total MAX OF CY01-CY03 PM STACK TEST DATA(4) Coal-fired Alternate Alt_fuel as Coal-fired Alternate Coal-fired Alternate Coal-fired Alternate Alt_fuel, % Coal Limestone By-Product Fugitive PAF Fugitive, % + SCR Fuels Total % of Total + SCR Fuels Total + SCR Fuels Total + SCR Fuels Total Blr Total Handling Handling Handling Total Total PAF Total

Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) 2478 0.0245 2478 0.001 2293 0.0379 2293 1207 0.123 1207 5978 0.186 5978 0.003 228 69.1 26.0 323 6301 5.1 PM < 10-micrometer aero. diam. (PM10_fil) 1685 0.0187 1685 0.001 1559 0.0190 1559 821 0.0660 821 4065 0.1036 4065 0.003 Not Not Not 4065 PM < 2.5-micrometer aero. diam. (PM2.5_fil) 892 0.00285 892 0.000 825 0.00474 825 435 0.0153 435 2152 0.0229 2152 0.001 Estimated Estimated Estimated 2152 Condensable PM (PM_cond) 467 0.0148 468 0.00 418 0.0247 418 2506 0.0794 2507 3392 0.119 3392 0.004 3392 Sulfur dioxide (SO2) 15146 0.368 15146 0.002 15804 0.539 15805 52972 2.08 52974 83922 2.99 83925 0.004 83925 Nitrogen oxides (NOx) 13145 0.313 13145 0.00 13040 0.455 13040 9090 1.51 9091 35274 2.28 35276 0.006 35276 Carbon monoxide (CO) 503 0.0819 503 0.02 450 0.0949 450 793 0.349 793 1746 0.526 1746 0.03 1746 Volatile organic compds (VOC) 111 0.00727 111 0.007 99 0.00379 99 174 0.0210 174 384 0.0321 384 0.008 384 Sulfuric acid (SO3/H2SO4) as H2SO4(5) 1202 0.0159 1202 0.001 1075 0.0265 1075 1289 0.0853 1289 3566 0.128 3566 0.004 3566 Ammonia (NH3)(6) 9.82E-04 9.82E-04 0.0 9.23E-04 9.23E-04 7.50 7.50 7.50 7.50 0.00 5.82 13.3 43.7

Trace-Element HAP Antimony (Sb) 3.48E-02 3.47E-05 3.49E-02 0.1 3.18E-02 5.78E-05 3.19E-02 1.55E-02 1.86E-04 1.57E-02 8.22E-02 2.79E-04 8.25E-02 0.3 7.79E-04 4.92E-05 1.25E-04 9.54E-04 8.34E-02 1.1 Arsenic (As) 5.90E-01 6.31E-06 5.90E-01 0.001 5.43E-01 1.05E-05 5.43E-01 2.02E-01 3.38E-05 2.02E-01 1.34E+00 5.06E-05 1.34E+00 0.004 1.67E-03 9.57E-05 4.98E-04 2.27E-03 1.34E+00 0.2 Beryllium (Be) 6.46E-02 4.73E-06 6.46E-02 0.01 6.00E-02 7.88E-06 6.00E-02 1.63E-02 2.54E-05 1.63E-02 1.41E-01 3.80E-05 1.41E-01 0.03 2.59E-04 1.03E-05 8.86E-05 3.58E-04 1.41E-01 0.3 Cadmium (Cd) 5.74E-02 5.16E-06 5.74E-02 0.01 5.22E-02 7.88E-06 5.22E-02 3.64E-02 2.58E-05 3.65E-02 1.46E-01 3.89E-05 1.46E-01 0.03 1.73E-04 1.98E-05 6.29E-05 2.56E-04 1.46E-01 0.2 Hydrogen chloride (HCl) 3.63E+01 1.77E-04 3.63E+01 0.0005 3.24E+01 0.00E+00 3.24E+01 4.90E+02 5.56E-03 4.90E+02 5.59E+02 5.73E-03 5.59E+02 0.001 5.59E+02 Chromium (Cr) 4.51E-01 5.13E-06 4.51E-01 0.001 4.12E-01 7.88E-06 4.12E-01 2.64E-01 2.58E-05 2.64E-01 1.13E+00 3.88E-05 1.13E+00 0.003 2.94E-03 3.62E-04 1.49E-03 4.79E-03 1.13E+00 0.4 Cobalt (Co) 1.04E-01 1.44E-05 1.04E-01 0.01 9.48E-02 2.39E-05 9.48E-02 5.85E-02 7.70E-05 5.86E-02 2.57E-01 1.15E-04 2.57E-01 0.04 1.98E-03 3.42E-05 9.68E-04 2.98E-03 2.60E-01 1.1 Hydrogen fluoride (HF) 1.03E+01 0.00E+00 1.03E+01 0.00 9.22E+00 0.00E+00 9.22E+00 9.84E+01 0.00E+00 9.84E+01 1.18E+02 0.00E+00 1.18E+02 0.00 1.18E+02 Lead (Pb) 6.93E-01 1.67E-05 6.93E-01 0.002 6.37E-01 2.36E-05 6.37E-01 2.88E-01 7.82E-05 2.88E-01 1.62E+00 1.19E-04 1.62E+00 0.01 2.82E-03 1.09E-04 8.42E-04 3.77E-03 1.62E+00 0.2 Manganese (Mn) 6.98E-01 1.40E-05 6.98E-01 0.002 6.37E-01 1.58E-05 6.37E-01 4.53E-01 5.57E-05 4.53E-01 1.79E+00 8.55E-05 1.79E+00 0.005 6.69E-03 5.47E-03 4.76E-03 1.69E-02 1.80E+00 0.9 Mercury (Hg) 7.94E-02 4.73E-06 7.94E-02 0.01 6.81E-02 7.88E-06 6.81E-02 1.29E-01 2.54E-05 1.29E-01 2.77E-01 3.80E-05 2.77E-01 0.01 2.10E-05 5.81E-07 5.11E-06 2.67E-05 2.77E-01 0.0 Nickel (Ni) 4.37E-01 5.41E-06 4.37E-01 0.001 3.97E-01 7.88E-06 3.97E-01 2.68E-01 2.62E-05 2.68E-01 1.10E+00 3.95E-05 1.10E+00 0.004 2.82E-03 2.32E-04 1.35E-03 4.40E-03 1.11E+00 0.4 Selenium (Se) 6.28E-01 2.36E-05 6.28E-01 0.004 5.62E-01 3.94E-05 5.62E-01 1.93E+00 1.27E-04 1.93E+00 3.12E+00 1.90E-04 3.12E+00 0.006 3.68E-04 8.89E-05 1.54E-04 6.12E-04 3.12E+00 0.0

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) 2.08E-02 2.08E-02 0.0 1.86E-02 1.86E-02 2.83E-02 2.83E-02 6.77E-02 6.77E-02 0.0 0.00E+00 6.77E-02 1,2-Dibromoethane (106934) 6.08E-02 6.08E-02 0.0 5.44E-02 5.44E-02 8.26E-02 8.26E-02 1.98E-01 1.98E-01 0.0 0.00E+00 1.98E-01 1,2-Dichloroethane (107062) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 1,2-Dichloropropane (78875) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 1,2,4-Trichlorobenzene (120821) 3.51E-02 3.51E-02 0.0 3.14E-02 3.14E-02 4.76E-02 4.76E-02 1.14E-01 1.14E-01 0.0 0.00E+00 1.14E-01 1,3-Dichloropropene (542756) 1.68E-02 1.68E-02 0.0 1.51E-02 1.51E-02 2.29E-02 2.29E-02 5.48E-02 5.48E-02 0.0 0.00E+00 5.48E-02 1,4-Dichlorobenzene (106467) 2.57E-02 2.57E-02 0.0 2.30E-02 2.30E-02 3.49E-02 3.49E-02 8.37E-02 8.37E-02 0.0 0.00E+00 8.37E-02 2-Butanone (78933) 7.25E-02 0.00E+00 7.25E-02 0.0 6.48E-02 0.00E+00 6.48E-02 9.85E-02 0.00E+00 9.85E-02 2.36E-01 0.00E+00 2.36E-01 0.0 0.00E+00 2.36E-01 2,4-Dinitrophenol (51285) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 2,4-Dinitrotoluene (121142) 4.67E-03 4.67E-03 0.0 4.18E-03 4.18E-03 6.35E-03 6.35E-03 1.52E-02 1.52E-02 0.0 0.00E+00 1.52E-02 2,4,6-Trichlorophenol (88062) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 3-Chloropropylene (107051) 2.13E-01 2.13E-01 0.0 1.90E-01 1.90E-01 2.89E-01 2.89E-01 6.92E-01 6.92E-01 0.0 0.00E+00 6.92E-01 4-Methyl-2-pentanone (108101) 5.38E-02 5.38E-02 0.0 4.81E-02 4.81E-02 7.31E-02 7.31E-02 1.75E-01 1.75E-01 0.0 0.00E+00 1.75E-01 4-Methylphenol (106445) 2.57E-02 2.57E-02 0.0 2.30E-02 2.30E-02 3.49E-02 3.49E-02 8.37E-02 8.37E-02 0.0 0.00E+00 8.37E-02 4-Nitrophenol (100027) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 Acetaldehyde (75070) 7.48E-02 0.00E+00 7.48E-02 0.0 6.69E-02 0.00E+00 6.69E-02 1.02E-01 0.00E+00 1.02E-01 2.43E-01 0.00E+00 2.43E-01 0.0 0.00E+00 2.43E-01 Acetophenone (98862) 2.80E-02 0.00E+00 2.80E-02 0.0 2.51E-02 0.00E+00 2.51E-02 3.81E-02 0.00E+00 3.81E-02 9.13E-02 0.00E+00 9.13E-02 0.0 0.00E+00 9.13E-02 Acrolein (107028) 4.44E-02 0.00E+00 4.44E-02 0.0 3.97E-02 0.00E+00 3.97E-02 6.04E-02 0.00E+00 6.04E-02 1.44E-01 0.00E+00 1.44E-01 0.0 0.00E+00 1.44E-01 Benzene (71432) 9.12E-02 0.00E+00 9.12E-02 0.0 8.15E-02 0.00E+00 8.15E-02 1.24E-01 0.00E+00 1.24E-01 2.97E-01 0.00E+00 2.97E-01 0.0 0.00E+00 2.97E-01 Benzyl chloride (100447) 6.54E-03 6.54E-03 0.0 5.85E-03 5.85E-03 8.89E-03 8.89E-03 2.13E-02 2.13E-02 0.0 0.00E+00 2.13E-02 Biphenyl (92524) 3.74E-03 3.74E-03 0.0 3.35E-03 3.35E-03 5.08E-03 5.08E-03 1.22E-02 1.22E-02 0.0 0.00E+00 1.22E-02 bis(2-Ethylhexyl)phthalate (117817) 8.41E-02 0.00E+00 8.41E-02 0.0 7.53E-02 0.00E+00 7.53E-02 1.14E-01 0.00E+00 1.14E-01 2.74E-01 0.00E+00 2.74E-01 0.0 1.27E-04 1.27E-04 2.74E-01 0.0 Bromomethane (74839) 2.08E-02 0.00E+00 2.08E-02 0.0 1.86E-02 0.00E+00 1.86E-02 2.83E-02 0.00E+00 2.83E-02 6.77E-02 0.00E+00 6.77E-02 0.0 0.00E+00 6.77E-02 Carbon disulfide (75150) 2.57E-02 2.57E-02 0.0 2.30E-02 2.30E-02 3.49E-02 3.49E-02 8.37E-02 8.37E-02 0.0 0.00E+00 8.37E-02 Carbon tetrachloride (56235) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 Chlorobenzene (108907) 3.74E-03 0.00E+00 3.74E-03 0.0 3.35E-03 0.00E+00 3.35E-03 5.08E-03 0.00E+00 5.08E-03 1.22E-02 0.00E+00 1.22E-02 0.0 0.00E+00 1.22E-02 Chloroethane (75003) 1.24E-02 1.24E-02 0.0 1.11E-02 1.11E-02 1.68E-02 1.68E-02 4.03E-02 4.03E-02 0.0 0.00E+00 4.03E-02 Chloroform (67663) 1.87E-02 0.00E+00 1.87E-02 0.0 1.67E-02 0.00E+00 1.67E-02 2.54E-02 0.00E+00 2.54E-02 6.08E-02 0.00E+00 6.08E-02 0.0 0.00E+00 6.08E-02 Chloromethane (74873) 2.57E-02 0.00E+00 2.57E-02 0.0 2.30E-02 0.00E+00 2.30E-02 3.49E-02 0.00E+00 3.49E-02 8.37E-02 0.00E+00 8.37E-02 0.0 0.00E+00 8.37E-02 Dibenzofuran (132649) 1.36E-02 1.36E-02 0.0 1.21E-02 1.21E-02 1.84E-02 1.84E-02 4.41E-02 4.41E-02 0.0 0.00E+00 4.41E-02 Dibutylphthalate (84742) 2.57E-03 2.57E-03 0.0 2.30E-03 2.30E-03 3.49E-03 3.49E-03 8.37E-03 8.37E-03 0.0 0.00E+00 8.37E-03 Dimethylphthalate (131113) 2.10E-03 2.10E-03 0.0 1.88E-03 1.88E-03 2.86E-03 2.86E-03 6.84E-03 6.84E-03 0.0 0.00E+00 6.84E-03 Ethyl benzene (100414) 1.87E-02 0.00E+00 1.87E-02 0.0 1.67E-02 0.00E+00 1.67E-02 2.54E-02 0.00E+00 2.54E-02 6.08E-02 0.00E+00 6.08E-02 0.0 0.00E+00 6.08E-02 Formaldehyde (50000) 6.08E-02 6.94E-04 6.15E-02 1.1 5.44E-02 1.16E-03 5.55E-02 8.26E-02 3.72E-03 8.63E-02 1.98E-01 5.58E-03 2.03E-01 2.7 0.00E+00 2.03E-01 n-Hexane (110543) 1.15E-02 1.15E-02 0.0 1.02E-02 1.02E-02 1.56E-02 1.56E-02 3.73E-02 3.73E-02 0.0 0.00E+00 3.73E-02 Hexachlorobenzene (118741) 9.58E-05 9.58E-05 0.0 8.57E-05 8.57E-05 1.30E-04 1.30E-04 3.12E-04 3.12E-04 0.0 0.00E+00 3.12E-04 Iodomethane (74884) 4.67E-02 4.67E-02 0.0 4.18E-02 4.18E-02 6.35E-02 6.35E-02 1.52E-01 1.52E-01 0.0 0.00E+00 1.52E-01 Isophorone (78591) 2.80E-02 2.80E-02 0.0 2.51E-02 2.51E-02 3.81E-02 3.81E-02 9.13E-02 9.13E-02 0.0 0.00E+00 9.13E-02 Methyl chloroform (71556) 1.43E-02 0.00E+00 1.43E-02 0.0 1.28E-02 0.00E+00 1.28E-02 1.94E-02 0.00E+00 1.94E-02 4.64E-02 0.00E+00 4.64E-02 0.0 0.00E+00 4.64E-02 Methyl methacrylate (80626) 2.57E-02 2.57E-02 0.0 2.30E-02 2.30E-02 3.49E-02 3.49E-02 8.37E-02 8.37E-02 0.0 0.00E+00 8.37E-02 Methylene chloride (75092) 8.41E-02 0.00E+00 8.41E-02 0.0 7.53E-02 0.00E+00 7.53E-02 1.14E-01 0.00E+00 1.14E-01 2.74E-01 0.00E+00 2.74E-01 0.0 0.00E+00 2.74E-01 Naphthalene (91203) 1.45E-02 0.00E+00 1.45E-02 0.0 1.30E-02 0.00E+00 1.30E-02 1.97E-02 0.00E+00 1.97E-02 4.71E-02 0.00E+00 4.71E-02 0.0 3.06E-04 2.25E-07 3.06E-04 4.75E-02 0.6 Pentachlorophenol (87865) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 Phenol (108952) 7.71E-02 0.00E+00 7.71E-02 0.0 6.90E-02 0.00E+00 6.90E-02 1.05E-01 0.00E+00 1.05E-01 2.51E-01 0.00E+00 2.51E-01 0.0 2.29E-03 2.29E-03 2.53E-01 0.9 Polychlorinated biphenyl [PCB] (1336363) 3.51E-04 0.00E+00 3.51E-04 0.0 3.14E-04 0.00E+00 3.14E-04 4.76E-04 0.00E+00 4.76E-04 1.14E-03 0.00E+00 1.14E-03 0.00 0.00E+00 1.14E-03 Propionaldehyde (123386) 4.44E-02 0.00E+00 4.44E-02 0.0 3.97E-02 0.00E+00 3.97E-02 6.04E-02 0.00E+00 6.04E-02 1.44E-01 0.00E+00 1.44E-01 0.00 0.00E+00 1.44E-01 Styrene (100425) 1.64E-02 0.00E+00 1.64E-02 0.0 1.46E-02 0.00E+00 1.46E-02 2.22E-02 0.00E+00 2.22E-02 5.32E-02 0.00E+00 5.32E-02 0.00 0.00E+00 5.32E-02 Tetrachloroethylene (127184) 9.82E-03 0.00E+00 9.82E-03 0.0 8.78E-03 0.00E+00 8.78E-03 1.33E-02 0.00E+00 1.33E-02 3.19E-02 0.00E+00 3.19E-02 0.00 0.00E+00 3.19E-02 Toluene (108883) 3.97E-02 0.00E+00 3.97E-02 0.0 3.55E-02 0.00E+00 3.55E-02 5.40E-02 0.00E+00 5.40E-02 1.29E-01 0.00E+00 1.29E-01 0.00 0.00E+00 1.29E-01 Trichloroethylene (79016) 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 N/A 0.00E+00 0.00E+00 Vinyl acetate (108054) 7.25E-03 7.25E-03 0.0 6.48E-03 6.48E-03 9.85E-03 9.85E-03 2.36E-02 2.36E-02 0.0 0.00E+00 2.36E-02 Vinyl chloride (75014) 1.71E-02 0.00E+00 1.71E-02 0.0 1.53E-02 0.00E+00 1.53E-02 2.32E-02 0.00E+00 2.32E-02 5.55E-02 0.00E+00 5.55E-02 0.0 0.00E+00 5.55E-02 Xylenes (1330207) 2.95E-02 0.00E+00 2.95E-02 0.0 2.63E-02 2.63E-02 4.00E-02 4.00E-02 9.58E-02 9.58E-02 0.0 0.00E+00 9.58E-02 Polycyclic organic matter (POM) 3.10E-02 3.76E-05 3.10E-02 0.1 2.77E-02 6.26E-05 2.78E-02 4.21E-02 2.01E-04 4.23E-02 1.01E-01 3.02E-04 1.01E-01 0.3 3.26E-03 8.72E-07 3.26E-03 1.04E-01 3.1 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) 9.12E-09 0.00E+00 9.12E-09 0.0 8.15E-09 0.00E+00 8.15E-09 1.24E-08 0.00E+00 1.24E-08 2.97E-08 0.00E+00 2.97E-08 0.0 0.00E+00 2.97E-08 Organic HAP Total 1.56E+00 7.32E-04 1.56E+00 0.0 1.40E+00 1.22E-03 1.40E+00 2.12E+00 3.93E-03 2.13E+00 5.09E+00 5.88E-03 5.09E+00 0.1 5.99E-03 1.10E-06 5.99E-03 5.10E+00 0.1
Ci/yr % Ci/yr Ci/yr Ci/yr % Ci/yr % Radionuclides 1.19E-01 1.19E-01 0.0 1.10E-01 1.10E-01 5.81E-02 5.81E-02 2.88E-01 2.88E-01 8.78E-04 8.78E-04 2.89E-01 0.3

Notes:

(1)CY06 PAF coal-region proximate coal-quality data from Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al. Region-specific coal-burn quantities were apportioned to each unit according to unit-specific total coal burn listed in Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI server; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.

(2)Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2005 Version 1 (3-29-06). Concentrations were weighted for each PAF coal-supply region by CY06 dry-basis tonnage burned in the plant/subplant. LT Model data were derived from EPRI's PISCES Database, except mercury (Hg) and chlorine (Cl) were taken from EPA's Information Collection Request (ICR) Part II coal database, May 2000. Coal-fired trace-element emission estimates in this file are based on LT Model coal concentrations, except for hydrogen chloride (HCl) estimates, which are based on Cl data from TVA's CY99 ICR analyses (per 3-16-00 e-mail from J.D. Eady to R.W. Burbage). PAF fines data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al. Concentrations of semivolatile organic compounds in coal (unspecified coal region) were taken from PISCES database as listed in 2-13-01 e-mail from P. Chu (EPRI) to I.J. Berty (SAIC) et al.

(3)Trace-element, organic HAP & radionuclide emissions were estimated using median emission factors from EPRI's "Emission Factors Handbook[EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants", Report No. EPRI TR-105611, Nov. 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update. For certain organic pollutants listed as nondetects in the EFH, emission factors were derived from EPRI's PISCES database using EFH procedures (per e-mails from J.D. Lokey to T.A Burnett [2-13-01] & to P. Chu [2-23-01]). Criteria-pollutant emissions were estimated from stack tests (filterable PM), continuous emission monitoring system (CEMS) data (SO2 & NOx), and AP-42 emission factors (condensable PM, CO & VOC) or particle-size distributions (PM10_fil & PM2.5_fil). Ash-handling fugitive-dust emissions of semivolatile organic compounds (e.g., POM) were estimated based on reported fly-ash and bottom-ash concentrations (5-29-01 e-mail from N. Goodman (EPRI) to J.D. Lokey).

(4)Filterable-PM stack test results listed in Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.

(5)"Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at US DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal-Fired Power Plants"); by L.S. Monroe, 5-01; by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"); and by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.

(6)Ammonia RY2005 Release Calculator model (v0.3), from S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05, TVA Environmental Technologies using CY06 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 03/26/07

Page 1 of 1

### BART

**Table 1A. TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Baseline Emission Estimates (English Units)** 

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **ft ft**  **ft ft/s**  **deg F lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 600 422 26.0 74.4 140 4779.58 357.77 4148.10 887.21 651.16 2.92E-04 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 600 422 26.0 74.4 140 4819.95 357.77 3976.85 904.56 660.34 3.07E-04 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 800 422 26.79 134 327 23068.10 431.00 3403.40 946.22 806.91 3.47 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 600 422 37.0 50.4 132 5166.75 584.95 3403.40 926.83 787.51 0.00E+00



### Table 1B.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Baseline Emission Estimates (Metric Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **m m**  **m m/s**  **K g/s**  **g/s g/s**  **g/s g/s**  **g/s**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 182.9 129 7.92 22.7 333 602.22 45.08 522.65 111.79 82.04 3.68E-05 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 182.9 129 7.92 22.7 333 607.30 45.08 501.07 113.97 83.20 3.87E-05 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 243.8 129 8.17 40.7 437 2906.53 54.30 428.82 119.22 101.67 4.38E-01 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 182.9 129 11.3 15.4 329 651.00 73.70 428.82 116.78 99.22 0.00E+00



### Table 2A.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Hydrated-Lime-Injection Emission Estimates (English Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **ft ft**  **ft ft/s**  **deg F lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 600 422 26.0 74.4 140 4779.58 141.29 4148.10 670.73 434.68 2.92E-04 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 600 422 26.0 74.4 140 4819.95 141.29 3976.85 688.08 443.87 3.07E-04 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 800 422 26.79 134 327 23068.10 232.61 3403.40 747.84 608.52 3.47 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 600 422 37.0 50.4 132 5166.75 232.61 3403.40 574.49 435.17 0.00E+00



### Table 2B.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Hydrated-Lime-Injection Emission Estimates (Metric Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **m m**  **m m/s**  **K g/s**  **g/s g/s**  **g/s g/s**  **g/s**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 182.9 129 7.92 22.7 333 602.22 17.80 522.65 84.51 54.77 3.68E-05 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 182.9 129 7.92 22.7 333 607.30 17.80 501.07 86.70 55.93 3.87E-05 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 243.8 129 8.17 40.7 437 2906.53 29.31 428.82 94.23 76.67 4.38E-01 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 182.9 129 11.3 15.4 329 651.00 29.31 428.82 72.38 54.83 0.00E+00 **PM 2.5**  

### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions **NO x** 



### Emissions **PM 10** 



### Emissions **Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **PM 2.5**  

### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions **NO x** 



### Emissions **PM 10** 



### Emissions **Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter** 

**Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions

**Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions



### Page 1 of 4

### BART

**Table 3A. TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Wet-ESP Case 1 (0.015 lb PM_fil/10^6 Btu) Emission Estimates (English Units)** 

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **ft ft**  **ft ft/s**  **deg F lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 600 422 26.0 74.4 140 4779.58 36.33 4148.10 135.15 101.75 2.92E-04 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 600 422 26.0 74.4 140 4819.95 36.33 3976.85 135.15 101.75 3.07E-04 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 800 422 26.79 134 327 23068.10 59.81 3403.40 395.85 340.86 3.47 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 600 422 37.0 50.4 132 5166.75 59.81 3403.40 222.50 167.51 0.00E+00



### Table 3B.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Wet-ESP Case 1 (0.015 lb PM_fil/10^6 Btu) Emission Estimates (Metric Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **m m**  **m m/s**  **K g/s**  **g/s g/s**  **g/s g/s**  **g/s**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 182.9 129 7.92 22.7 333 602.22 4.58 522.65 17.03 12.82 3.68E-05 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 182.9 129 7.92 22.7 333 607.30 4.58 501.07 17.03 12.82 3.87E-05 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 243.8 129 8.17 40.7 437 2906.53 7.54 428.82 49.88 42.95 4.38E-01 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 182.9 129 11.3 15.4 329 651.00 7.54 428.82 28.04 21.11 0.00E+00



### Table 4A.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Wet-ESP Case 2 (0.030 lb PM_fil/10^6 Btu) Emission Estimates (English Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **ft ft**  **ft ft/s**  **deg F lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 600 422 26.0 74.4 140 4779.58 36.33 4148.10 206.13 139.32 2.92E-04 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 600 422 26.0 74.4 140 4819.95 36.33 3976.85 206.13 139.32 3.07E-04 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 800 422 26.79 134 327 23068.10 59.81 3403.40 512.71 402.73 3.47 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 600 422 37.0 50.4 132 5166.75 59.81 3403.40 339.37 229.38 0.00E+00



### Table 4B.**TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Wet-ESP Case 2 (0.030 lb PM_fil/10^6 Btu) Emission Estimates (Metric Units)**

**latitude longitude**  **Datum UT** **M East UT** **M North UT** **M Zone Datum**  **deg. deg.**  **km km**  **m m**  **m m/s**  **K g/s**  **g/s g/s**  **g/s g/s**  **g/s**

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 182.9 129 7.92 22.7 333 602.22 4.58 522.65 25.97 17.55 3.68E-05 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 182.9 129 7.92 22.7 333 607.30 4.58 501.07 25.97 17.55 3.87E-05 PAF3B TVA - PAF U3 - Bypass 37.260 86.980 501.78 4123.48 16 243.8 129 8.17 40.7 437 2906.53 7.54 428.82 64.60 50.74 4.38E-01 PAF3F TVA - PAF U3 - FGD 501.70 4123.49 16 182.9 129 11.3 15.4 329 651.00 7.54 428.82 42.76 28.90 0.00E+00 **Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions

**Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions

**Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions

**Stack ID # Company/Source**  **Location Location UTM**  **Stack Height**  **Base**

**Elevation Diameter**  **NO x**  

### Emissions **PM 10** 



### Emissions **PM 2.5** 



### Emissions **NH 3** 



### Emissions **Gas Exit Velocity**  **Stack Gas**

**Exit Temp. SO** **2**



### Emissions **H 2** 

### SO**4**



### Emissions



### Page 2 of 4

### BART

**Table 1A.**

PAF1 PAF2 PAF3B PAF3F



### Table 1B.

PAF1 PAF2 PAF3B PAF3F



### Table 2A.

PAF1 PAF2 PAF3B PAF3F



### Table 2B.

PAF1 PAF2 PAF3B PAF3F **Stack ID # Stack ID #** 

**Stack ID #**

**Stack ID # Condensable Particulate Matter (CPM)**  **Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)**

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

56.54 43.46 13.92 13.92 178.88 178.88 88.518 147.531 103.272 36.883 115.576 0.000 0.000 0.000 0.000 9.826 501.605 57.37 42.63 13.92 13.92 178.88 178.88 91.580 152.634 106.844 38.159 119.574 0.000 0.000 0.000 0.000 10.165 518.956 31.29 68.71 109.59 109.59 215.50 215.50 52.244 87.073 60.951 21.768 68.213 0.000 0.000 0.000 0.000 5.799 296.049 31.94 68.06 22.91 22.91 292.47 292.47 52.244 87.073 60.951 21.768 68.213 0.000 0.000 0.000 0.000 5.799 296.049

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s**

56.54 43.46 1.75 1.75 22.54 22.54 11.153 18.589 13.012 4.647 14.562 0.000 0.000 0.000 0.000 1.238 63.201 57.37 42.63 1.75 1.75 22.54 22.54 11.539 19.232 13.462 4.808 15.066 0.000 0.000 0.000 0.000 1.281 65.387 31.29 68.71 13.81 13.81 27.15 27.15 6.583 10.971 7.680 2.743 8.595 0.000 0.000 0.000 0.000 0.731 37.302 31.94 68.06 2.89 2.89 36.85 36.85 6.583 10.971 7.680 2.743 8.595 0.000 0.000 0.000 0.000 0.731 37.302

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

74.78 25.22 13.92 13.92 70.64 70.64 88.518 147.531 103.272 36.883 115.576 0.000 0.000 0.000 0.000 9.826 501.605 75.42 24.58 13.92 13.92 70.64 70.64 91.580 152.634 106.844 38.159 119.574 0.000 0.000 0.000 0.000 10.165 518.956 39.59 60.41 109.59 109.59 116.31 116.31 52.244 87.073 60.951 21.768 68.213 0.000 0.000 0.000 0.000 5.799 296.049 51.53 48.47 22.91 22.91 116.31 116.31 52.244 87.073 60.951 21.768 68.213 0.000 0.000 0.000 0.000 5.799 296.049

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s**

74.78 25.22 1.75 1.75 8.90 8.90 11.153 18.589 13.012 4.647 14.562 0.000 0.000 0.000 0.000 1.238 63.201 75.42 24.58 1.75 1.75 8.90 8.90 11.539 19.232 13.462 4.808 15.066 0.000 0.000 0.000 0.000 1.281 65.387 39.59 60.41 13.81 13.81 14.65 14.65 6.583 10.971 7.680 2.743 8.595 0.000 0.000 0.000 0.000 0.731 37.302 51.53 48.47 2.89 2.89 14.65 14.65 6.583 10.971 7.680 2.743 8.595 0.000 0.000 0.000 0.000 0.731 37.302



### Page 3 of 4

### BART

**Table 3A.**

PAF1 PAF2 PAF3B PAF3F



### Table 3B.

PAF1 PAF2 PAF3B PAF3F



### Table 4A.

PAF1 PAF2 PAF3B PAF3F



### Table 4B.

PAF1 PAF2 PAF3B PAF3F **Stack ID #**

**Stack ID #**

**Stack ID #**

**Stack ID # Condensable Particulate Matter (CPM)**  **Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)**

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

52.52 47.48 13.92 13.92 18.17 18.17 12.526 20.877 14.614 5.219 16.355 0.000 0.000 0.000 0.000 1.390 70.982 52.52 47.48 13.92 13.92 18.17 18.17 12.526 20.877 14.614 5.219 16.355 0.000 0.000 0.000 0.000 1.390 70.982 29.52 70.48 109.59 109.59 29.91 29.91 20.623 34.371 24.060 8.593 26.926 0.000 0.000 0.000 0.000 2.289 116.861 52.52 47.48 22.91 22.91 29.91 29.91 20.623 34.371 24.060 8.593 26.926 0.000 0.000 0.000 0.000 2.289 116.861

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s**

52.52 47.48 1.75 1.75 2.29 2.29 1.578 2.630 1.841 0.658 2.061 0.000 0.000 0.000 0.000 0.175 8.944 52.52 47.48 1.75 1.75 2.29 2.29 1.578 2.630 1.841 0.658 2.061 0.000 0.000 0.000 0.000 0.175 8.944 29.52 70.48 13.81 13.81 3.77 3.77 2.598 4.331 3.031 1.083 3.393 0.000 0.000 0.000 0.000 0.288 14.724 52.52 47.48 2.89 2.89 3.77 3.77 2.598 4.331 3.031 1.083 3.393 0.000 0.000 0.000 0.000 0.288 14.724

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr lb/hr**  **lb/hr**

68.87 31.13 13.92 13.92 18.17 18.17 25.052 41.754 29.228 10.439 32.710 0.000 0.000 0.000 0.000 2.781 141.964 68.87 31.13 13.92 13.92 18.17 18.17 25.052 41.754 29.228 10.439 32.710 0.000 0.000 0.000 0.000 2.781 141.964 45.59 54.41 109.59 109.59 29.91 29.91 41.245 68.742 48.119 17.186 53.852 0.000 0.000 0.000 0.000 4.578 233.723 68.87 31.13 22.91 22.91 29.91 29.91 41.245 68.742 48.119 17.186 53.852 0.000 0.000 0.000 0.000 4.578 233.723

**Condensable Particulate Matter (CPM) Filterable Particulate Matter < 10-micrometer (μm) aerodynamic diameter (PM10_fil)** 

**particle speciation Organic CPM (CPM-ORG)**  **Inorganic CPM (CPM-IOR), taken to be H2SO4**  **Coarse PM Soil**  **Elemental Carbon (EC) Total** 
**filterable PM** **10** 

### condensable

**PM 10**  

### 0.625-1.0 μm **< 0.625 μm 0.625-1.0 μm**  **< 0.625 μm 6-10 μm**  **2.5-6 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm 1.25-2.5 μm**  **1.0-1.25 μm 0.625-1.0 μm**  **< 0.625 μm PM10_fil**  **% %**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s g/s**  **g/s**

68.87 31.13 1.75 1.75 2.29 2.29 3.157 5.261 3.683 1.315 4.121 0.000 0.000 0.000 0.000 0.350 17.887 68.87 31.13 1.75 1.75 2.29 2.29 3.157 5.261 3.683 1.315 4.121 0.000 0.000 0.000 0.000 0.350 17.887 45.59 54.41 13.81 13.81 3.77 3.77 5.197 8.661 6.063 2.165 6.785 0.000 0.000 0.000 0.000 0.577 29.449 68.87 31.13 2.89 2.89 3.77 3.77 5.197 8.661 6.063 2.165 6.785 0.000 0.000 0.000 0.000 0.577 29.449

Total 0.625-1.0 μm < 0.625 μm 0.625-1.0 μm < 0.625 μm 6-10 μm 2.5-6 μm 1.25-2.5 μm 1.0-1.25 μm 0.625-1.0 μm < 0.625 μm 1.25-2.5 μm 1.0-1.25 μm 0.625-1.0 μm < 0.625 μm 

### PM10_fil 50.00 50.00 50.00 50.00 17.647 29.412 20.588 7.353 23.041 0.000 0.000 0.000 0.000 1.959 100.000

*Reference: "Particulate Speciation Profiles for Selected Source Types" posted 3-16-06 on VISTAS website providing CALPUFF modeling information for BART applications (http://vistas-sesarm.org/BART/calpuff.asp); PM speciation files from this website correspond with Excel files (e.g., "2006FinalCycloneFurnaceESPpmSpeciationProfile.xls") downloaded from National Park Service (NPS) website (http://www2.nature.nps.gov/air/permits/ect/ectCoalFiredBoiler.cfm) 

### TVA Environmental Technologies 39167.000 Assumed CPM-ORG Assumed CPM-IOR **Fraction (%) of Filterable PM10 (PM10_fil) in each class/size range*** Particle-Size Distributn, % Particle-Size Distributn, % Coarse Soil Elemental Carbon (EC)



### Page 4 of 4Inputs

**Table 8. Gaseous-Species Emission Parameters & Molecular Wts Table 9. EPRI EFH Recommended Emission Factor** * Boiler Coal Boiler SO3 Production, Median Gas-phase Fraction at Stack* **(as % of Coal Input)** Type Type SO3/SO2 Molar Ratio Nitrogen Oxides (NOx), Sulfur Oxides (SOx) as SO2, Without FGD With FGD Molecular Coal Type/Contrl Sys Pollutant Control Dry-bottom Low-S Eastern Bituminous (LSE) 0.0082 Coal Type lb/(ton as-fired coal) lb/(ton as-fired coal*%S) Pollutant Scrubbers Scrubbers Weight** (Se, HCl, HF) Se HCl HF Hg Device (Hg) Pulverized- High-S Eastern Bituminous (HSE) 0.011 Bituminous 33 38 Chloride (Cl) 0.993 0.953 35.453 Bituminous/non-FGD 55 100 90 ** non-FGD Coal (PC) Western Bituminous 0.00111 Subbituminous 17 35 Fluoride (F) 0.986 0.920 18.9984 Lignite/non-FGD 55 100 90 ** FGD

Subbituminous (PRB) 0.0018 Hydrogen chloride (HCl) 36.4609 Subbituminous 3 20 50 Lignite 0.0048 *Reference: US EPA, Compilation of Air Pollutant Emission Factors (AP-42), Hydrogen fluoride (HF) 20.0063 Bitum or Lignite/FGD 12 3 6 Cyclone Low-S Eastern Bituminous (LSE) 0.0082 Vol. I, 5th Edition, Supplement E, Section 1.1, "Bituminous and Subbituminous Mercury (Hg) 200.59

High-S Eastern Bituminous (HSE) 0.016 Coal Combustion", Table 1.1-3, Sept. 98. Selenium (Se) 78.96 *Reference: Emission Factors Handbook (EFH) Guidelines for Estimating Trace Western Bituminous 0.0022 Sulfur (S) 32.064 Substance Emissions from Fossil Fuel Steam Electric Plants, Electric Power Subbituminous (PRB) 0.0018 **Table 7. Particulate-Matter (PM) Particle-Size Distribution for** Sulfur Dioxide (SO2) 64.0628 Research Institute (EPRI), EPRI TR-105611, 11-95, as updated in 9-98 & 2-01 Lignite 0.00112 **Cyclone-Fired Boilers Burning Bituminous Coal*** Sulfur Trioxide (SO3) 80.0622 EFH Addenda and in the Apr. 2002 EFH revision. Sulfuric Acid (H2SO4) 98.0774 Particle Size Ammonia 17.0304 **Apr. 02 EFH Revision predicts Hg removal using correlation equations developed Boiler Coal SO3/H2SO4 Penetration (Aerodynamic Ammonium Hydroxide (NH4OH) 35.0456 from 1999 ICR stack-test program results. Hg removal varies with chloride content Type Type Factr ( = 1 - contrl efficncy) Equiv. Diameter), Electrostatic Nitrogen Oxides (NOx) as Nitrogen Dioxide (NO2) 46.0055 of coal. Different correlation equations are listed for various types of air-pollution All Low-S Eastern Bituminous (LSE) 0.49 Micrometers Uncontrolled Precipitator (ESP) control equipment. High-S Eastern Bituminous (HSE) 0.85 10 13 68 *Reference: PISCES Version 2.1 Release Notes, Addendum 3-6-98 Western & Subbituminous (PRB) 0.56 6 8 56 Note: FGD = flue-gas desulfurization, e.g., limestone scrubber. 2.5 5.5 36 **Reference: Chemical Engineers' Handbook, 5th Edition, 1.25 5 22 R.H. Perry & C.H. Chilton, Editors, 1973 Eqpmt Coal SO3/H2SO4 Penetration 1 5 17 Type Type Factr ( = 1 - contrl efficncy) 0.625 0 Cold-side Low-S Eastern Bituminous (LSE) 0.49 ESP High-S Eastern Bituminous (HSE) 0.77 *Reference: US EPA, Compilation of Air Pollutant Emission Factors (AP-42),

Western & Subbituminous (PRB) 0.73 Vol. I, 5th Edition, Supplement E, Section 1.1, Table 1.1-8, Sept. 98. Hot ESP All 0.63 Bagfilter (BF)All 0.10 No data were given in Table 1.1-8 for particle-size distributions for cyclone-fired coal boilers controlled by flue-gas-desulfurization (FGD) scrubbers. PAF Units 1-2 PM-10 and PM-2.5 emssns were estimated using the particle-size distribution for Eqpmt Coal SO3/H2SO4 Penetration cyclone-fired boilers controlled by ESP. Type Type Factr ( = 1 - contrl efficncy) Wet Spray Eastern Bituminous 0.47 **Table 7A. Fine Filterable PM (PM2.5_fil) Chemical Speciation*** Tower PRB/Lignite 0.40 Wet VenturiAll 0.65 Elemental Carbon (EC), Soil (e.g., flyash), Dry FGD/BFAll 0.01 Equipment Type % of PM2.5_fil % of PM2.5_fil Mg-Ox mixedAll 0.50 Coal-fired Boilers 3.7 96.3 with fuel oil Mg-Ox into All 0.50 *Reference: US EPA, Draft "Catalog of Global Emissions Inventories and Emission furnace Inventory Tools for Black Carbon", Jan. 2002, as cited in "Particulate Speciation Profiles for Selected Source Types" posted 3-16-06 on website providing CALPUFF modeling **Table 5. SCR SO2 Oxidation (F3_SCR) Factrs*** information for VISTAS BART applications (http://vistas-sesarm.org/BART/calpuff.asp) Eqpmt Coal SCR SO3/H2SO4 Production Type Type Factr (alkaline-ash adjustmt) **Table 7B. Total Condensable PM (CPM-TOT) Emission Factors*** All boilers PRB Subbituminous 0.17

Other coals 1.00 Emission Factor (lb/10^6 Btu) vs. coal sulfur (S) content (%) Equipment Type Coal S <= 0.4% by weight Coal S > 0.4% by weight Nominal Stack Flue-gas O2 Concentratn, % Vol = 6.0 PC Blr w/o FGD 0.01 =0.1*S-0.03 Nominal Flue-gas H2O Concentratn, % Vol = 8.1 PC Blr w/ FGD 0.02 0.02 Cyclone Blr w/o FGD 0.01 =0.1*S-0.03 NOTE: O2 concen. is used to estimate approx. SO3 volumetric concentration for Cyclone Blr w/ FGD 0.02 0.02 comparison purposes. The SO3/H2SO4 mass emission rate (tpy) is estimated AFBC Blr 0.02 0.02 based on SO3/SO2 molar ratio, so precise O2 concen. aren't needed (changing the O2 concen. doesn't change the H2S04 mass emission rate, only ppm SO3). **Table 7C. Condensable Particulate Matter (CPM) Chemical Speciation***
*Reference: "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Inorganic CPM (CPM-IOR), Organic CPM (CPM-ORG), Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at U.S. Equipment Type % of CPM-TOT % of CPM-TOT DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur PC Blr w/o FGD 80 20 Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, 3-98; revised by K. Harrison, PC Blr w/ FGD ND, assume same as aboveND, assume same as above 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Cyclone Blr w/o FGD 80 20 Acid Emissions from Coal-Fired Power Plants"); and by L.S. Monroe, 5-01, by Cyclone Blr w/ FGD ND, assume same as aboveND, assume same as above L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"), and *Reference: US EPA, Compilation of Air Pollutant Emission Factors (AP-42), by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Vol. I, 5th Edition, Supplement E, Section 1.1, Table 1.1-5, Sept. 98. Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
Note: High-sulfur E. bituminous coal is defined as >= 2.5 % S, per 2-17-06 e-mail TVA Environmental Technologies from K.E. Harrison to J.D. Lokey et al. 03/26/07 **Table 4. Wet/Dry FGD Eqpmt SO3/H2SO4 Penetratn (F2) Factrs*** **Table 1. Coal-fired Boiler SO3/H2SO4 Production (F1) Factors*** **Table 6. Uncontrolled Cyclone-Furnace Emission Factors***

**Table 2. Air-Heater (AH) SO3/H2SO4 Penetration (F2) Factors***

**Table 3. PM-Control Eqpmt SO3/H2SO4 Penetratn (F2) Factrs*** PM Cumulative Size Distribution, Cumulative Mass % < Stated Size

Page 1 of 1

# Outputs

Estimated Elemental Concentrations in PAF Solids Streams, mg/kg

PAF 1-2 PAF 1-3 PAF 1-3 PAF 1-3 PAF 1-2

Species Coal (dry) Coal (dry) Bottom Ash + Pyr Fly Ash to

Ash PondGypsum Sb 2.37 4.08 3.43 219 14.5 As 10.96 8.76 8.9 206 67.9 Ba 75.1 102.1 798 716 294 Be 1.64 1.35 3.09 28.2 8.8 Cd 1.03 0.90 2.67 19.0 5.17 Cl 618 488 67.0 686 4017 Cr 18.5 15.4 92 189 60.0 Co 12.9 10.4 57.7 124 43.0 Cu 12.1 11.3 39.2 262 56.8 F 8.68 15.7 38.5 373 82.1 Pb 18.5 14.8 17.9 336 108 Mn 39.6 35.0 342 128 84.4 Hg 0.112 0.110 0.316 0.30 0.201 Mo 11.9 10.0 42.5 170 54.5 Ni 16.7 14.7 81 220 59.2 Se 2.36 1.93 7.9 18.5 9.6 Ag 0.12 0.184 1.48 1.70 0.315 Tl 2.10 2.30 6.08 63.9 11.6 V 70.1 57.3 383 585 184 Zn 53.5 43.2 109 899 274 Note: PAF 1-2 Fly_Ash_Capture to gypsum stack = 90%Remainder goes to slag pond (economizer ash) PAF Unit 3 Fly_Ash_Capture to ash pond = 100% *Reference: PISCES Model (ver. 3.11) outputs, obtained from 3-11-02 P31 file on "envshr" drive .

Page 1calcs

**Sample Calculations for CY06 Paradise Fossil Plant (PAF) Unit 1 Coal-fired Criteria-Pollutant & Hazardous-Air-Pollutant (HAP) Emission Estimates**
General Input Variables: Value Units Notes Reference
coal_burn_PAF1_2 = 3,813,191tons/yr (tpy) CY06 PAF Units 1-2 as received/fired (AR) coal burn (total for all coal-supply regions) 1 coal_burn_PAF3 = 3,170,658tpy CY06 PAF Unit 3 AR coal burn (total for all coal-supply regions) 1 coal_burn_PAF1_2_ILB = 3,679,729tpy CY06 PAF Units 1-2 AR Illinois Basin (ILB) bituminous coal burn 1 coal_burn_PAF1_2_PRB = 61,011tpy CY06 PAF Units 1-2 AR Powder River Basin (PRB) subbituminous coal burn 1 coal_burn_PAF1_2_ILB_fines = 72,451tpy CY06 PAF Units 1-2 AR ILB bituminous coal-fines coal burn 1 coal_burn_PAF3_ILB = 1,318,994tpy CY06 PAF Unit 3 AR ILB bituminous coal burn 1 coal_burn_PAF3_PRB = 1,791,422tpy CY06 PAF Unit 3 AR PRB subbituminous coal burn 1 coal_burn_PAF3_ILB_fines = 60,242tpy CY06 PAF Unit 3 AR ILB bituminous coal-fines burn 1 coal_burn_PAF1_opstat = 1,994,961tpy CY06 PAF Unit 1 AR coal burn (total for all coal-supply regions), as listed in DataFuser Operating Statistics 2 coal_burn_PAF2_opstat = 1,784,432tpy CY06 PAF Unit 2 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF1_2_opstat = 3,779,393tpy CY06 PAF Units 1-2 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF3_opstat = 3,116,082tpy CY06 PAF Unit 3 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF3_preFGD_opstat = 2,515,183tpy CY06 PAF Unit 3 AR coal burn (all coal-supply regions) before flue-gas-desulfurization (FGD) scrubber installed 2 coal_burn_PAF3_postFGD_opstat = 600,899tpy CY06 PAF Unit 3 AR coal burn (all coal-supply regions) after FGD scrubber installed 2 coal_burn_PAF3_preFGD_ILB_fines_coalstat = 65,164tpy CY06 PAF Unit 3 AR ILB bituminous coal-fines burn before FGD scrubber installed 36 coal_burn_PAF3_postFGD_ILB_fines_coalstat = 69,952tpy CY06 PAF Unit 3 AR ILB bituminous coal-fines burn after FGD scrubber installed 36 coal_H2O_PAF_ILB = 10.9%-weight CY06 PAF ILB coal H2O content 1 coal_H2O_PAF_PRB = 26.7%-weight CY06 PAF PRB coal H2O content 1 coal_H2O_PAF_ILB_fines = 24.0%-weight CY06 PAF ILB coal-fines H2O content 1 coal_ash_PAF_ILB = 8.71%-weight CY06 PAF ILB coal AR ash content 1 coal_ash_PAF_PRB = 5.42%-weight CY06 PAF PRB coal AR ash content 1 coal_ash_PAF_ILB_fines = 27.4%-weight CY06 PAF ILB coal-fines AR ash content 1 coal_S_PAF_ILB = 2.78%-weight CY06 PAF ILB coal AR sulfur content 1 coal_S_PAF_PRB = 0.29%-weight CY06 PAF PRB coal AR sulfur content 1 coal_S_PAF_ILB_fines = 3.06%-weight CY06 PAF ILB coal-fines AR sulfur content 1 coal_heat_PAF_ILB = 11,756Btu [HHV]/lb CY06 PAF ILB coal AR heat content (higher heating value [HHV]) 1 coal_heat_PAF_PRB = 8,851Btu [HHV]/lb CY06 PAF PRB coal AR heat content (HHV) 1 coal_heat_PAF_ILB_fines = 6,673Btu [HHV]/lb CY06 PAF ILB coal-fines AR heat content (higher heating value [HHV]) 1 PM_fil_emssn_factr_PAF1_coal = 0.106lb/10^6 Btu (MBtu) Maximum of CY01-CY03 PAF Unit 1 coal-fired filterable particulate-matter (PM_fil) stack-test measurements 3 ash_partition_to_flue_gas_PAF = 25% TVA data for ash distribution in PAF cyclone-furnace coal-fired boilers 4 PM_fil_sub10_ESP = 68% Cumulative PM_fil mass % <= 10 micrometers for bituminous-fired cyclone blrs w/ electrostatic precipitator (ESP) 5 PM_fil_sub6_ESP = 56% Cumulative PM_fil mass % <= 6 micrometers for bituminous-fired cyclone blrs w/ ESP 5 PM_fil_sub2.5_ESP = 36% Cumulative PM_fil mass % <= 2.5 micrometers for bituminous-fired cyclone blrs w/ ESP 5 PM_fil_sub1.25_ESP = 22% Cumulative PM_fil mass % <= 1.25 micrometer for bituminous-fired cyclone blrs w/ ESP 5 PM_fil_sub1_ESP = 17% Cumulative PM_fil mass % <= 1.0 micrometer for bituminous-fired cyclone blrs w/ ESP 5 PM_cond_emssn_factr_coal_FGD = 0.02lb/MBtu Condensable particulate-matter (PM_cond) emssn factr for cyclone blrs w/ flue-gas-desulfurization (FGD) scrubber 5 PM_cond_org_fractn = 20% Organic fraction (%) of total PM_cond emissns for cyclone blrs (use same factr as for pulverized-coal [PC] blrs) 5 CO_uncontrlld_emssn_factr_coal = 0.5lb/(ton AR coal) Uncontrolled carbon monoxide (CO) emssn factr for cyclone-fired blrs 5 VOC_uncontrlld_emssn_factr_coal = 0.11lb/(ton AR coal) Uncontrolled volatile organic compound (VOC) emssn factr for cyclone-fired blrs 5 SO2_emssn_PAF1_CEMS = 15,146tpy CY06 PAF Unit 1 CEMS sulfur dioxide (SO2) emssn data (coal + alternate fuels) 6 NOx_emssn_PAF1_CEMS = 13,145tpy CY06 PAF Unit 1 CEMS nitrogen oxides (NOx) emssn data (coal + alternate fuels) 6 heat_input_PAF1_CEMS = 44,104,732x 10^6 Btu/yr (MBtu/yr) CY06 PAF Unit 1 CEMS heat-input estimate (coal + alternate fuels) 6
max _heat_input_PAF1 = 6,959x 10^6 Btu/hr (MBtu/hr) PAF Unit 1 maximum rated heat-input capacity, per Title V permit application 32
max _heat_input_PAF3 = 11,457MBtu/hr PAF Unit 3 maximum rated heat-input capacity, per Title V permit application 32 PM2.5_fil_EC_fractn = 3.7% Elemental-carbon (EC) fraction (%) of PM_fil < 2.5 micrometers for coal-fired blrs 34
PM & Gaseous Trace-Element HAP Inputs:
Pb_in_ILB_mass = 14mg/kg (dry basis) Median lead (Pb) concentration in Illinois Basin (ILB) bituminous coal 7 Pb_in_PRB_mass = 3.2mg/kg (dry basis) Median Pb concentration in Powder River Basin (PRB) subbituminous coal 7 Pb_in_ILB_fines_mass = 32mg/kg (dry basis) Average Pb concentration in Illinois Basin (ILB) bituminous coal fines 8 Cl_in_ILB_mass = 602mg/kg (AR) CY99 Information Collection Request (ICR) AR chloride (Cl) concen. in PAF ILB coal receipts 9 Cl_in_PRB_mass = 50mg/kg (AR) CY99 ICR AR Cl concentration in PAF PRB coal receipts 9 Cl_in_ILB_fines_mass = 158mg/kg (dry basis) Average Cl concentration in Illinois Basin (ILB) bituminous coal fines 8 Hg_in_ILB_mass = 0.08mg/kg (dry basis) Median mercury (Hg) concentration in ILB bitum. coal 7 Hg_in_PRB_mass = 0.06mg/kg (dry basis) Median Hg concentration in PRB subbitum. coal 7 Hg_in_ILB_fines_mass = 0.221mg/kg (dry basis) Average Hg concentration in Illinois Basin (ILB) bituminous coal fines 8 Cl_contrl_effncy_FGD = 97% Emission Factor Hdbk (EFH) average Cl contrl effncy for coal-fired blrs w/ flue-gas-desulfurizatn (FGD) scrubber 10 Cl_mol_wt = 35.453lb/lb-mole Chlorine atomic weight 11 HCl_mol_wt = 36.4609lb/lb-mole Hydrogen chloride molecular weight 11 Hg_removal_multiplier_FGDW= 0.0582dimensionless EFH Hg contrl-effncy equatn parameter for blrs w/ wet FGD scrubber but no electrostatic-precipitator (ESP) 10 Hg_removal_constant_FGDW= -0.1932dimensionless EFH Hg contrl-effncy equatn parameter for blrs w/ wet FGD scrubber but no electrostatic-precipitator (ESP) 10 Hg_removal_effncy_SCR_FGDW_bitum = 86% Hg removal efficiency for Eastern-bitum-fired boilers w/selective-catalytic-reduction (SCR) reactor & FGD scrubber 10

**PA F Units 1-3 Coal-Burn and Heat-Input Estimates** 
Equation (1): coal_burn_PAF = coal_burn_PAF1_2+coal_burn_PAF3 coal_burn_PAF = 6,983,849tons/yr (tpy)
Equation (2): coal_burn_PAF1_ILB = coal_burn_PAF1_2_ILB*coal_burn_PAF1_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF1_ILB = 1,942,353tpy CY06 PAF Unit 1 Illinois Basin (ILB) bitum. coal AR coal-burn quantity (burn share based on PAF Operating Stats)
Equation (3): coal_burn_PAF1_PRB = coal_burn_PAF1_2_PRB*coal_burn_PAF1_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF1_PRB = 32,205tpy CY06 PAF Unit 1 Powder River Basin (PRB) subbitum. coal AR coal-burn quantity (burn share based on PAF OpStats)
Equation (4): coal_burn_PAF1_ILB_fines = coal_burn_PAF1_2_ILB_fines*coal_burn_PAF1_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF1_ILB_fines = 38,243tpy CY06 PAF Unit 1 Illinois Basin (ILB) bitum. coal-fines AR coal-burn quantity (burn share based on PAF Operating Stats)
Equation (5): coal_burn_PAF1 = coal_burn_PAF1_ILB+coal_burn_PAF1_PRB+coal_burn_PAF1_ILB_fines CY06 PAF Unit 1 AR coal burn (total for all coal-supply regions) coal_burn_PAF1 = 2,012,801tpy
Equation (6): coal_burn_PAF2_ILB = coal_burn_PAF1_2_ILB*coal_burn_PAF2_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF2_ILB = 1,737,376tpy CY06 PAF Unit 2 ILB bitum. coal AR coal-burn quantity (burn share based on PAF Operating Stats)
Equation (7): coal_burn_PAF2_PRB = coal_burn_PAF1_2_PRB*coal_burn_PAF2_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF2_PRB = 28,806tpy CY06 PAF Unit 2 PRB subbitum. coal AR coal-burn quantity (burn share based on PAF coal stats)
Equation (8): coal_burn_PAF2_ILB_fines = coal_burn_PAF1_2_ILB_fines*coal_burn_PAF2_opstat/coal_burn_PAF1_2_opstat coal_burn_PAF2_ILB_fines = 34,208tpy CY06 PAF Unit 2 Illinois Basin (ILB) bitum. coal-fines AR coal-burn quantity (burn share based on PAF Operating Stats)
Equation (9): coal_burn_PAF3_preFGD_adjusted = coal_burn_PAF3_preFGD_opstat*coal_burn_PAF3/coal_burn_PAF3_opstat coal_burn_PAF3_preFGD_adjusted = 2,559,235tpy
Equation (10): coal_burn_PAF3_postFGD_adjusted = coal_burn_PAF3_postFGD_opstat*coal_burn_PAF3/coal_burn_PAF3_opstat coal_burn_PAF3_postFGD_adjusted = 611,423tpy
Equation (11): coal_burn_PAF3_preFGD_ILB_fines = coal_burn_PAF3_ILB_fines*coal_burn_PAF3_preFGD_ILB_fines_coalstat/(coal_burn_PAF3_preFGD_ILB_fines_coalstat+coal_burn_PAF3_postFGD_ILB_fines_coalstat) coal_burn_PAF3_preFGD_ILB_fines = 29,054tpy
Equation (12): coal_burn_PAF3_postFGD_ILB_fines = coal_burn_PAF3_ILB_fines*coal_burn_PAF3_postFGD_ILB_fines_coalstat/(coal_burn_PAF3_preFGD_ILB_fines_coalstat+coal_burn_PAF3_postFGD_ILB_fines_coalstat)

Page 1 of 16calcs

coal_burn_PAF3_postFGD_ILB_fines = 31,188tpy
Equation (13): coal_burn_PAF3_preFGD_PRB = coal_burn_PAF3_PRB coal_burn_PAF3_preFGD_PRB = 1,791,422tpy
Equation (14): coal_burn_PAF3_postFGD_PRB = coal_burn_PAF3_PRB - coal_burn_PAF3_preFGD_PRB coal_burn_PAF3_postFGD_PRB = 0tpy
Equation (15): coal_burn_PAF3_preFGD_ILB = coal_burn_PAF3_preFGD_adjusted - coal_burn_PAF3_preFGD_ILB_fines - coal_burn_PAF3_preFGD_PRB coal_burn_PAF3_preFGD_ILB = 738,759tpy
Equation (16): coal_burn_PAF3_postFGD_ILB = coal_burn_PAF3_postFGD_adjusted - coal_burn_PAF3_postFGD_ILB_fines - coal_burn_PAF3_postFGD_PRB coal_burn_PAF3_postFGD_ILB = 580,235tpy
Equation (17): heat_input_PAF1_ILB = coal_burn_PAF1_ILB*(2000 lb/ton)*coal_heat_PAF_ILB*(TBtu/10^12 Btu) heat_input_PAF1_ILB = 45.67TBtu/yr
Equation (18): heat_input_PAF1_PRB = coal_burn_PAF1_PRB*(2000 lb/ton)*coal_heat_PAF_PRB*(TBtu/10^12 Btu) heat_input_PAF1_PRB = 0.57TBtu/yr
Equation (19): heat_input_PAF1_ILB_fines = coal_burn_PAF1_ILB_fines*(2000 lb/ton)*coal_heat_PAF_ILB_fines*(TBtu/10^12 Btu) heat_input_PAF1_ILB_fines = 0.51TBtu/yr
Equation (20): heat_input_PAF1_coal = heat_input_PAF1_ILB+heat_input_PAF1_PRB+heat_input_PAF1_ILB_fines heat_input_PAF1_coal = 46.75TBtu/yr
Equation (21): heat_input_PAF3_preFGD_ILB = coal_burn_PAF3_preFGD_ILB*(2000 lb/ton)*coal_heat_PAF_ILB*(TBtu/10^12 Btu) heat_input_PAF3_preFGD_ILB = 17.37TBtu/yr
Equation (22): heat_input_PAF3_preFGD_PRB = coal_burn_PAF3_preFGD_PRB*(2000 lb/ton)*coal_heat_PAF_PRB*(TBtu/10^12 Btu) heat_input_PAF3_preFGD_PRB = 31.71TBtu/yr
Equation (23): heat_input_PAF3_preFGD_ILB_fines = coal_burn_PAF3_preFGD_ILB_fines*(2000 lb/ton)*coal_heat_PAF_ILB_fines*(TBtu/10^12 Btu) heat_input_PAF3_preFGD_ILB_fines = 0.39TBtu/yr
Equation (24): heat_input_PAF3_preFGD_coal = heat_input_PAF3_preFGD_ILB+heat_input_PAF3_preFGD_PRB+heat_input_PAF3_preFGD_ILB_fines heat_input_PAF3_preFGD_coal = 49.47TBtu/yr
Equation (25): heat_input_PAF3_postFGD_ILB = coal_burn_PAF3_postFGD_ILB*(2000 lb/ton)*coal_heat_PAF_ILB*(TBtu/10^12 Btu) heat_input_PAF3_postFGD_ILB = 13.64TBtu/yr
Equation (26): heat_input_PAF3_postFGD_PRB = coal_burn_PAF3_postFGD_PRB*(2000 lb/ton)*coal_heat_PAF_PRB*(TBtu/10^12 Btu) heat_input_PAF3_postFGD_PRB = 0.00TBtu/yr
Equation (27): heat_input_PAF3_postFGD_ILB_fines = coal_burn_PAF3_postFGD_ILB_fines*(2000 lb/ton)*coal_heat_PAF_ILB_fines*(TBtu/10^12 Btu) heat_input_PAF3_postFGD_ILB_fines = 0.42TBtu/yr
Equation (28): heat_input_PAF3_postFGD_coal = heat_input_PAF3_postFGD_ILB+heat_input_PAF3_postFGD_PRB+heat_input_PAF3_postFGD_ILB_fines heat_input_PAF3_postFGD_coal = 14.06TBtu/yr

**PA F Unit 1 BART Baseline Coal-fired Criteria-Pollutant Emission Estimates:** 
Coal-fired total filterable particulate-matter (PM_fil) emissions were estimated from maximum of CY01-CY03 stack-test results. Filterable PM10 and PM2.5 emissions for PAF Units 1-3 were estimated based on AP-42 particle-size distributions for cyclone-fired boilers with electrostatic-precipitator (ESP) PM control systems. No particle-size distribution data were listed for cyclone-fired boilers with flue-gas-desulfurization (FGD) scrubbers. Sulfur dioxide (SO2) and nitrogen oxides (NOx) emission estimates reflect continuous emission monitoring system (CEMS) data (coal-fired SO2 & NOx emissions were estimated by subtracting alternate-fuel estimates from CEMS data). Condensable PM, carbon monoxide (CO), and volatile organic compound (VOC) emission estimates were derived from AP-42 emission factors.
Filterable Particulate Matter (PM_fil)
Equation (1): PM_fil_emssn_PAF1_coal = heat_input_PAF1_coal*(10^6 MBtu/TBtu)*PM_fil_emssn_factr_PAF1_coal*(ton/2000 lb) PM_fil_emssn_PAF1_coal = 2.48E+03tpy This value is listed in cell F21 of "PAF1" wksheet (PAF1!F21) and also in cell B13 of "air" worksheet.
Equation (2): PM_fil_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM_fil_emssn_factr_PAF1_coal PM_fil_emssn_PAF1_coal_hrly = 7.38E+02 lb/unit-hr This value, listed in cell PAF1!G21, is based on maximum PM_fil emssn factr & Title V max heat-input capacity.
Equation (3): PM10_fil_emssn_PAF1_coal = PM_fil_emssn_PAF1_coal*PM_ESP_%PM10/100 PM10_fil_emssn_PAF1_coal = 1.68E+03tpy This value is listed in cell PAF1!F22 and also in cell B14 of "air" worksheet.
Equation (4): PM10_fil_emssn_factr_PAF1_coal = PM10_fil_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) PM10_fil_emssn_factr_PAF1_coal = 7.21E-02 lb/MBtu
Equation (5): PM10_fil_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM10_fil_emssn_factr_PAF1_coal PM10_fil_emssn_PAF1_coal_hrly = 5.02E+02 lb/unit-hr This value, listed in cell PAF1!G22, is based on estimated PM10_fil emssn factr & Title V max heat-input capacity.
Equation (6): PM2.5_fil_emssn_PAF1_coal = PM_fil_emssn_PAF1_coal*PM_ESP_%PM2.5/100 PM2.5_fil_emssn_PAF1_coal = 8.92E+02tpy This value is listed in cell PAF1!F23 and also in cell B15 of "air" worksheet.
Equation (7): PM2.5_fil_emssn_factr_PAF1_coal = PM2.5_fil_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) PM2.5_fil_emssn_factr_PAF1_coal = 3.82E-02 lb/MBtu
Equation (8): PM2.5_fil_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM2.5_fil_emssn_factr_PAF1_coal PM2.5_fil_emssn_PAF1_coal_hrly = 2.66E+02 lb/unit-hr This value, listed in cell PAF1!G23, is based on estimated PM2.5_fil emssn factr & Title V max heat-input capacity.
Equation (9): PM2.5_fil_EC_emssn_PAF1_coal_hrly = PM2.5_fil_emssn_PAF1_coal_hrly*PM2.5_fil_EC_fractn/100 PM2.5_fil_EC_emssn_PAF1_coal_hrly = 9.83E+00 lb/unit-hr EC fractn of PM2.5_fil emssn, listed in cell AM7 of "BART" worksheet, assigned entirely to smallest CALPUFF size range.
Condensable Particulate Matter (PM_cond)
Equation (1): PM_cond_emssn_PAF1_coal = heat_input_PAF1_coal*(10^6 MBtu/TBtu)*PM_cond_emssn_factr_coal_FGD*(ton/2000 lb) PM_cond_emssn_PAF1_coal = 4.67E+02tpy This value is listed in cell PAF1!F24 and also in cell B16 of "air" worksheet.

Page 2 of 16calcs

Equation (2): PM_cond_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM_cond_emssn_factr_coal_FGD PM_cond_emssn_PAF1_coal_hrly = 1.39E+02 lb/unit-hr This value, listed in cell PAF1!G24, is based on estimated PM_cond emssn factr & Title V max heat-input capacity.
Equation (3): PM_cond_org_emssn_PAF1_coal_hrly = PM_cond_emssn_PAF1_coal_hrly*PM_cond_organic_fractn/100 PM_cond_org_emssn_PAF1_coal_hrly = 2.78E+01 lb/unit-hr Organic portion of PM_cond emssn, equally apportioned between cells Y7 and Z7 in "BART" worksheet
AP-42 indicates that all condensable-PM particles are presumed to be less than 1 micron in diameter. PM_cond emissions were assumed to be split equally between the 2 submicron CALPUFF particle-size ranges. 5
Filterable-PM Particle-Size Speciation
Equation (1): PM10_fil_fractn_6_10 = (PM_fil_sub10_ESP - PM_fil_sub6_ESP)/PM_fil_sub10_ESP*100 PM10_fil_fractn_6_10 = 17.6% Fraction (%) of PM10_fil in size range between 6 and 10 micrometers
Equation (2): PM10_fil_fractn_2.5_6 = (PM_fil_sub6_ESP - PM_fil_sub2.5_ESP)/PM_fil_sub10_ESP*100 PM10_fil_fractn_2.5_6 = 29.4% Fraction (%) of PM10_fil in size range between 2.5 and 6 micrometers
Equation (3): PM10_fil_fractn_1.25_2.5 = (PM_fil_sub2.5_ESP - PM_fil_sub1.25_ESP)/PM_fil_sub10_ESP*100 PM10_fil_fractn_1.25_2.5 = 20.6% Fraction (%) of PM10_fil in size range between 1.25 and 2.5 micrometers
Equation (4): PM10_fil_fractn_1_1.25 = (PM_fil_sub1.25_ESP - PM_fil_sub1_ESP)/PM_fil_sub10_ESP*100 PM10_fil_fractn_1_1.25 = 7.4% Fraction (%) of PM10_fil in size range between 1 and 1.25 micrometer
Equation (5): PM10_fil_fractn_sub1 = (PM_fil_sub1_ESP)/PM_fil_sub10_ESP*100 PM10_fil_fractn_sub1 = 25.0% AP-42 cyclone-boiler PM_fil particle-size distributn contains no data for size range < 0.625 micrometer.
Equation (6): PM10_fil_fractn_6_10_emssn_PAF1_coal_hrly = PM10_fil_emssn_PAF1_coal_hrly*PM10_fil_fractn_6_10/100 PM10_fil_fractn_6_10_emssn_PAF1_coal_hrly = 8.85E+01 lb/unit-hr This value, listed in cell BART!AD7, is presumed to consist entirely of soil (flyash) components.
Equation (7): PM10_fil_fractn_2.5_6_emssn_PAF1_coal_hrly = PM10_fil_emssn_PAF1_coal_hrly*PM10_fil_fractn_2.5_6/100 PM10_fil_fractn_2.5_6_emssn_PAF1_coal_hrly = 1.48E+02 lb/unit-hr This value, listed in cell BART!AE7, is presumed to consist entirely of soil (flyash) components.
Equation (8): PM10_fil_fractn_1.25_2.5_emssn_PAF1_coal_hrly = PM10_fil_emssn_PAF1_coal_hrly*PM10_fil_fractn_1.25_2.5/100 PM10_fil_fractn_1.25_2.5_emssn_PAF1_coal_hrly =1.03E+02 lb/unit-hr This value, listed in cell BART!AF7, is presumed to consist entirely of soil (flyash) components.
Equation (9): PM10_fil_fractn_1_1.25_emssn_PAF1_coal_hrly = PM10_fil_emssn_PAF1_coal_hrly*PM10_fil_fractn_1_1.25/100 PM10_fil_fractn_1_1.25_emssn_PAF1_coal_hrly = 3.69E+01 lb/unit-hr This value, listed in cell BART!AG7, is presumed to consist entirely of soil (flyash) components.
Equation (10): PM10_fil_sub1_emssn_PAF1_coal_hrly = PM10_fil_emssn_PAF1_coal_hrly*PM10_fil_fractn_sub1/100 PM10_fil_sub1_emssn_PAF1_coal_hrly = 1.25E+02 lb/unit-hr
Equation (11): PM10_fil_sub1_flyash_emssn_PAF1_coal_hrly = PM10_fil_sub1_emssn_PAF1_coal_hrly - PM2.5_fil_EC_emssn_PAF1_coal_hrly PM10_fil_sub1_flyash_emssn_PAF1_coal_hrly = 1.16E+02 lb/unit-hr Submicron PM_fil minus elemental carbon (EC) = soil (flyash) components, listed in cell BART!AH7
Submicron PM_fil soil (flyash) components were assigned to the 0.625-to-1 micrometer CALPUFF size range, based on cyclone coal-fired boiler PM-speciation guidance posted on the National Park Service (NPS) website. 35
Carbon Monoxide (CO)
Equation (1): CO_emssn_PAF1_coal = (coal_burn_PAF1_ILB+coal_burn_PAF1_PRB+coal_burn_PAF1_ILB_fines)*CO_uncontrlld_emissn_factr_coal*(ton/2000 lb) CO_emssn_PAF1_coal = 5.03E+02tpy This value is listed in cell PAF1!F27 and also in cell B19 of "air" worksheet.
Volatile Organic Compounds (VOC)
Equation (1): VOC_emssn_PAF1_coal = (coal_burn_PAF1_ILB+coal_burn_PAF1_PRB+coal_burn_PAF1_ILB_fines)*VOC_uncontrlld_emissn_factr_coal*(ton/2000 lb) VOC_emssn_PAF1_coal = 1.11E+02tpy This value is listed in cell PAF1!F28 and also in cell B20 of "air" worksheet.
No sample calculations are needed for annual coal-fired boiler SO2 and NOx emission estimates since they are based on CEMS measurements. The following explains hourly SO2 and NOx emission estimates.
Sulfur Dioxide (SO2)
Equation (1): SO2_emssn_factr_PAF1_CEMS = SO2_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS SO2_emssn_factr_PAF1_CEMS = 0.687lb/MBtu
Equation (2): SO2_emssn_PAF1_coal_hrly = max_heat_input_PAF1*SO2_emssn_factr_PAF1_CEMS SO2_emssn_PAF1_coal_hrly = 4.78E+03 lb/unit-hr This value, listed in cell PAF1!G25, is based on CY06-average CEMS SO2 emssn factr & Title V max heat-input capacity.
Nitrogen Oxides (NOx)
Equation (1): NOx_emssn_factr_PAF1_CEMS = NOx_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS NOx_emssn_factr_PAF1_CEMS = 0.596lb/MBtu
Equation (2): NOx_emssn_PAF1_coal_hrly = max_heat_input_PAF1*NOx_emssn_factr_PAF1_CEMS NOx_emssn_PAF1_coal_hrly = 4.15E+03 lb/unit-hr This value, listed in cell PAF1!G26, is based on CY06-average CEMS NOx emssn factr & Title V max heat-input capacity.

**PA F BART Baseline Coal-fired Sulfur Trioxide (SO3)/Sulfuric Acid (H2SO4) Emission Estimates** 
General Input Variables: Value Units Notes Reference
bitum_S_to_SOx = 95% Bituminous coal-sulfur conversion to sulfur oxides (SOx) 12 subbit_S_to_SOx = 87.5% Subbituminous coal-sulfur conversion to sulfur oxides (SOx) 12 SO3_to_SO2_molar_ratio_LSE = 0.82% SO3/SO2 ratio for cyclone-fired boilers burning low-sulfur (<2.5% S) Eastern (LSE) bituminous coals 12 SO3_to_SO2_molar_ratio_HSE = 1.6% SO3/SO2 ratio for cyclone-fired boilers burning medium- to high-sulfur (>=2.5% S) Eastern (HSE) bitum. coals 12 SO3_to_SO2_molar_ratio_WB = 0.22% SO3/SO2 ratio for cyclone-fired boilers burning Western bituminous (WB) coals 12 SO3_to_SO2_molar_ratio_Sub = 0.18% SO3/SO2 ratio for cyclone-fired boilers burning subbituminous (Sub) coals 12 AH_SO3_contrl_effncy_LSE = 51% SO3 control efficiency for air heaters (AH) in units burning low-sulfur (<2.5% S) Eastern (LSE) bitum. coals 12 AH_SO3_contrl_effncy_HSE = 15% SO3 control efficiency for air heaters (AH) in units burning high-sulfur (>=2.5% S) Eastern (HSE) bitum. coals 12 AH_SO3_contrl_effncy_WC = 44% SO3 control efficiency for AH in units burning W. bitum. & subbit. (WC) coals 12 ESP_SO3_contrl_effncy_LSE = 51% SO3 control efficiency for cold-side electrostatic precipitators (ESP) in units burning low-S E. bitum. (LSE) coals 12 ESP_SO3_contrl_effncy_HSE = 23% SO3 control efficiency for cold-side ESP in units burning high-S E. bitum. (HSE) coals 12 ESP_SO3_contrl_effncy_WC = 27% SO3 control efficiency for cold-side ESP in units burning W. bitum. & subbit. (WC) coals 12 BF_SO3_contrl_effncy = 90% SO3 control efficiency for bagfilters (BF) 12 WST_SO3_contrl_effncy_EB = 53% SO3 control efficiency for wet spray tower (WST) FGD scrubbers in units burning Eastern bitum. (EB) coals 12 WST_SO3_contrl_effncy_WC = 60% SO3 control efficiency for WST FGD scrubbers in units burning Western bitum. & subbitum. (WC) coals 12 WV_SO3_contrl_effncy = 35% SO3 control efficiency for wet venturi (WV) FGD scrubbers 12 Dry_FGD_BF_SO3_contrl_effncy = 99% SO3 control efficiency for dry flue-gas-desulfurization (FGD) scrubbers with downstream bagfilter controls 12 H2SO4_to_SO3_molar_ratio = 100% Assume all SO3 converted to H2SO4 downstrm of air heater 12 flue_gas_factr_dry = 9,780dry std ft^3/MBtu Dry flue-gas factor for bitum & subbit. coals at 0% excess air 12

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flue_gas_factr_wet_0%O2 = 10,640wet std ft^3/MBtu Wet flue-gas factor for bitum & subbit. coals at 0% excess air 12 flue_gas_O2_concen = 3%-volume (dry basis) Flue-gas O2 concentration used as standard for TVA test measurements (typical coal-fired AH-inlet O2 level) SO2_conv_factr = 1.66E-07(lb/std ft^3)/ppmv SO2 factor to convert from mass/volume concentration to parts per million by volume (ppmv) 12 H2SO4_conv_factr = 2.54E-07(lb/std ft^3)/ppmv H2SO4 factor to convert from mass/volume concentration to ppmv 12 S_mol_wt = 32.064lb/lb-mole Sulfur (S) molecular weight 11 SO2_mol_wt = 64.0628lb/lb-mole Sulfur dioxide (SO2) molecular weight 11 H2SO4_mol_wt = 98.0774lb/lb-mole Sulfuric acid (H2SO4) molecular weight 11 blr_operatn_hrs_PAF1 = 8,029hours/year (hr/yr) PAF Unit 1 boiler total in-service hours 2 blr_operatn_hrs_PAF3_preFGD = 5,289hr/yr PAF Unit 3 boiler total in-service hours before flue-gas-desulfurization (FGD) scrubber installation 2 blr_operatn_hrs_PAF3_postFGD = 1,473hr/yr PAF Unit 3 boiler total in-service hours after flue-gas-desulfurization (FGD) scrubber installation 2 SCR_operatn_hrs_PAF1 = 3,308hr/yr PAF Unit 1 selective-catalytic-reduction (SCR) reactor total in-service hours (in flue-gas path) 13 SCR_operatn_hrs_PAF3_preFGD = 3,338hr/yr PAF Unit 3 SCR reactor total in-service hours (in flue-gas path) before FGD scrubber installation 13 SCR_operatn_hrs_PAF3_postFGD = 0hr/yr PAF Unit 3 SCR reactor total in-service hours (in flue-gas path) after FGD scrubber installation 13 SCR_NH3_operatn_hrs_PAF1 = 3,300hr/yr PAF Unit 1 SCR reactor in-service hours (with ammonia [NH3] feed) 13 SCR_NH3_operatn_hrs_PAF3_preFGD = 3,304hr/yr PAF Unit 3 SCR reactor in-service hours (with ammonia [NH3] feed) before FGD scrubber installation 13 SCR_NH3_operatn_hrs_PAF3_postFGD = 0hr/yr PAF Unit 3 SCR reactor in-service hours (with ammonia [NH3] feed) after FGD scrubber installation 13 SCR_SO2_oxidatn_rate = 0.75% PAF design SCR-reactor catalyst SO2 oxidation rate 14 NH3_slip = 2ppmv on dry basis (ppmvd) Vendor-guaranteed maximum SCR-exit dry flue-gas NH3 concentration (slip) at 20,000 SCR operating hours 15 molar_vol_STP = 359.036ft^3/lb-mole at STP Molar volume of gas at temperature = 0 deg C and pressure = 760 mm Hg (ideal-gas-law equation) 12 F3_SCR_PRB = 17% SCR SO3/H2SO4 production factor (alkaline-ash adjustment factor) for PRB subbituminous coals 12 F3_SCR_Other = 100% SCR SO3/H2SO4 production factor (alkaline-ash adjustment factor) for other (non-PRB) coals 12 flue_gas_SO3_concen_stk_PAF_SCR_byp_FGD = 14.2ppmvd at 3% O2 CY05 test data for PAF Unit 2 stack-exit SO3/H2SO4 dry flue-gas concentration with bypassed SCR reactor 16 flue_gas_SO3_concen_stk_PAF_SCR_FGD = 17.7ppmvd at 3% O2 CY05 test data for PAF Unit 2 stack-exit SO3/H2SO4 dry flue-gas concentration with in-service SCR reactor 16
PAF Unit 1 Total Coal-fired SO3/H2SO4 Emission Estimates (Flue-Gas-Concentration Method):
Equation (1): SCR_oper_factr_PAF1 = SCR_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 SCR_oper_factr_PAF1 = 4.12E-01(dimensionless) Nominal fraction of PAF Unit 1 coal burn while SCR reactor was in flue-gas path
Equation (2):
max _SCR_oper_factr_PAF1 = blr_operatn_hrs_PAF1/blr_operatn_hrs_PAF1
max _SCR_oper_factr_PAF1 = 1.00E+00 BART (maximum short-term) emissions were estimated using 1.0 for the total SCR operation factor
Equation (3): flue_gas_SO3_concen_stk_exit_PAF1_avg = flue_gas_SO3_concen_stk_PAF_SCR_byp_FGD*(1-max_SCR_oper_factr_PAF1)+flue_gas_SO3_concen_stk_PAF_SCR_FGD*max_SCR_oper_factr_PAF1 flue_gas_SO3_concen_stk_exit_PAF1_avg = 1.77E+01ppmvd at 3% O2
Equation (4): H2SO4_emssn_PAF1_coal = heat_input_PAF1_coal*(10^6 MBtu/TBtu)*flue_gas_factr_dry*20.9/(20.9-flue_gas_O2_concen)*flue_gas_SO3_concen_stk_exit_PAF1_avg*H2SO4_conv_factr*(ton/2000 lb) H2SO4_emssn_PAF1_coal = 1.20E+03tpy H2SO4 PAF Unit 1 coal-fired blr- & SCR-derived contributn to SO3/H2SO4 emissns, listed in PAF1!F29 and in air!B21.
Equation (5): H2SO4_emssn_factr_PAF1_coal = H2SO4_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) H2SO4_emssn_factr_PAF1_coal = 5.14E-02lb/MBtu
Equation (6): H2SO4_emssn_PAF1_coal_hrly = max_heat_input_PAF1*H2SO4_emssn_factr_PAF1_coal H2SO4_emssn_PAF1_coal_hrly = 3.58E+02lb/unit-hr This value, listed in cell PAF1!G29, is based on estimated H2SO4 emssn factr & Title V max heat-input capacity.
PAF Unit 3 Pre-FGD Coal-fired Boiler Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method):
PAF Unit 3 Pre-FGD Illinois Basin (ILB) bituminous coal:
Equation (1): Blr_exit_SOx_PAF3_preFGD_ILB = coal_burn_PAF3_preFGD_ILB*coal_S_PAF_ILB/100*bitum_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_preFGD_ILB = 3.90E+04tpy
Equation (2): Blr_H2SO4_productn_PAF3_preFGD_ILB = Blr_exit_SOx_PAF3_preFGD_ILB*SO3_to_SO2_molar_ratio_HSE/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_preFGD_ILB = 9.55E+02tpy
Equation (3): Blr_H2SO4_emssn_PAF3_preFGD_ILB = Blr_H2SO4_productn_PAF3_preFGD_ILB*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100) Blr_H2SO4_emssn_PAF3_preFGD_ILB = 6.25E+02tpy PAF Unit 3 pre-FGD ILB-coal boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns
PAF Unit 3 Pre-FGD Powder River Basin (PRB) subbituminous coal:
Equation (4): Blr_exit_SOx_PAF3_preFGD_PRB = coal_burn_PAF3_preFGD_PRB*coal_S_PAF_PRB/100*subbit_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_preFGD_PRB = 9.08E+03tpy
Equation (5): Blr_H2SO4_productn_PAF3_preFGD_PRB = Blr_exit_SOx_PAF3_preFGD_PRB*SO3_to_SO2_molar_ratio_sub/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_preFGD_PRB = 2.50E+01tpy
Equation (6): Blr_H2SO4_emssn_PAF3_preFGD_PRB = Blr_H2SO4_productn_PAF3_preFGD_PRB*(1-AH_SO3_contrl_effncy_WC/100)*(1-ESP_SO3_contrl_effncy_WC/100) Blr_H2SO4_emssn_PAF3_preFGD_PRB = 1.02E+01tpy PAF Unit 3 pre-FGD PRB-coal boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns
PAF Unit 3 Pre-FGD Illinois Basin (ILB) bituminous coal fines:
Equation (7): Blr_exit_SOx_PAF3_preFGD_ILB_fines = coal_burn_PAF3_preFGD_ILB_fines*coal_S_PAF_ILB_fines/100*bitum_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_preFGD_ILB_fines = 1.69E+03tpy
Equation (8): Blr_H2SO4_productn_PAF3_preFGD_ILB_fines = Blr_exit_SOx_PAF3_preFGD_ILB_fines*SO3_to_SO2_molar_ratio_HSE/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_preFGD_ILB_fines = 4.13E+01tpy
Equation (9): Blr_H2SO4_emssn_PAF3_preFGD_ILB_fines = Blr_H2SO4_productn_PAF3_preFGD_ILB_fines*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy/100) Blr_H2SO4_emssn_PAF3_preFGD_ILB_fines = 2.71E+01tpy PAF Unit 3 pre-FGD ILB coal-fines boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns

PAF Unit 3 Pre-FGD total-coal boiler combustion-derived SO3/H2SO4 emssn:
Equation (10): Blr_H2SO4_productn_PAF3_preFGD_coal = Blr_H2SO4_productn_PAF3_preFGD_ILB+Blr_H2SO4_productn_PAF3_preFGD_PRB+Blr_H2SO4_productn_PAF3_preFGD_ILB_fines Blr_H2SO4_productn_PAF3_preFGD_coal = 1.02E+03tpy
Equation (11): Blr_H2SO4_emssn_PAF3_preFGD_coal = Blr_H2SO4_emssn_PAF3_preFGD_ILB+Blr_H2SO4_emssn_PAF3_preFGD_PRB+Blr_H2SO4_emssn_PAF3_preFGD_ILB_fines Blr_H2SO4_emssn_PAF3_preFGD_coal = 6.62E+02tpy PAF Unit 3 pre-FGD coal-fired blr combustn-derived contributn to SO3/H2SO4 emissns
Equation (12): Blr_H2SO4_contrl_effncy_PAF3_preFGD = (1-Blr_H2SO4_emssn_PAF3_preFGD_coal/Blr_H2SO4_productn_PAF3_preFGD_coal)*100 Blr_H2SO4_contrl_effncy_PAF3_preFGD = 35.15%
Equation (13): Blr_H2SO4_flue_gas_concen_PAF3_preFGD = Blr_H2SO4_emssn_PAF3_preFGD_coal*(2000 lb/ton)/heat_input_PAF3_preFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr Blr_H2SO4_flue_gas_concen_PAF3_preFGD = 9.23E+00ppmvd at 3% O2 Coal-fired blr combustion-derived contributn to PAF Unit 3 pre-FGD stk-exit SO3/H2SO4 flue-gas concentration
PAF Unit 3 Pre-FGD Selective-catalytic-reduction (SCR) Reactor-Derived SO3/H2SO4 Emission Estimates (HSD Method):
PAF Unit 3 Pre-FGD Illinois Basin (ILB) bituminous coal:

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Equation (1): SCR_oper_factr_PAF3_preFGD = SCR_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD SCR_oper_factr_PAF3_preFGD = 6.31E-01(dimensionless) Nominal fraction of PAF Unit 3 pre-FGD coal burn while SCR reactor was in flue-gas path
Equation (2):
max _SCR_oper_factr_PAF3_preFGD = blr_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD
max _SCR_oper_factr_PAF3_preFGD = 1.00E+00 BART (maximum short-term) emissions were estimated using 1.0 for the total SCR operation factor
Equation (3): SCR_H2SO4_productn_PAF3_preFGD_ILB = Blr_exit_SOx_PAF3_preFGD_ILB*SCR_SO2_oxidatn_rate/100*F3_SCR_Other/100*max_SCR_oper_factr_PAF3_preFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_preFGD_ILB = 4.48E+02tpy
Equation (4): SCR_NH3_oper_factr_PAF3_preFGD = SCR_NH3_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD SCR_NH3_oper_factr_PAF3_preFGD = 6.25E-01(dimensionless) Fraction of PAF Unit 3 pre-FGD coal burn while SCR reactor was in flue-gas path with NH3 inputs
Equation (5): NH3_neutrlztn_PAF3_preFGD_ILB = heat_input_PAF3_preFGD_ILB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_preFGD*flue_gas_factr_dry*20.9/(20.9- flue_gas_O2_concen)*NH3_slip/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_preFGD_ILB = 3.15E+01tpy PAF Unit 3 pre-FGD ILB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (6): SCR_H2SO4_emssn_PAF3_preFGD_ILB = (SCR_H2SO4_productn_PAF3_preFGD_ILB-NH3_neutrlztn_PAF3_preFGD_ILB)*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100) SCR_H2SO4_emssn_PAF3_preFGD_ILB = 2.72E+02tpy SCR-derived contributn to PAF Unit 3 pre-FGD ILB stack-exit SO3/H2SO4 emissns
PAF Unit 3 Pre-FGD Powder River Basin (PRB) subbituminous coal:
Equation (7): SCR_H2SO4_productn_PAF3_preFGD_PRB = Blr_exit_SOx_PAF3_preFGD_PRB*SCR_SO2_oxidatn_rate/100*F3_SCR_PRB/100*max_SCR_oper_factr_PAF3_preFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_preFGD_PRB = 1.77E+01tpy H2SO4
Equation (8): NH3_neutrlztn_PAF3_preFGD_PRB = heat_input_PAF3_preFGD_PRB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_preFGD*flue_gas_factr_dry*20.9/(20.9- flue_gas_O2_concen)*NH3_slip/10^6/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_preFGD_PRB = 5.76E+01tpy H2SO4 PAF Unit 3 pre-FGD PRB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (9): SCR_H2SO4_emssn_PAF3_preFGD_PRB = (SCR_H2SO4_productn_PAF3_preFGD_PRB-NH3_neutrlztn_PAF3_preFGD_PRB)*(1-AH_SO3_contrl_effncy_WC/100)*(1-ESP_SO3_contrl_effncy_WC/100) SCR_H2SO4_emssn_PAF3_preFGD_PRB = -1.63E+01tpy H2SO4 SCR-derived contributn to PAF Unit 3 pre-FGD PRB stack-exit SO3/H2SO4 emissns
PAF Unit 3 Pre-FGD Illinois Basin (ILB) bituminous coal fines:
Equation (10): SCR_H2SO4_productn_PAF3_preFGD_ILB_fines = Blr_exit_SOx_PAF3_preFGD_ILB_fines*SCR_SO2_oxidatn_rate/100*F3_SCR_Other/100*max_SCR_oper_factr_PAF3_preFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_preFGD_ILB_fines = 1.94E+01tpy
Equation (11): NH3_neutrlztn_PAF3_preFGD_ILB_fines = heat_input_PAF3_preFGD_ILB_fines*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_preFGD*flue_gas_factr_dry*20.9/(20.9- flue_gas_O2_concen)*NH3_slip/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_preFGD_ILB_fines = 7.04E-01tpy PAF Unit 3 pre-FGD ILB-coal-fines-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (12): SCR_H2SO4_emssn_PAF3_preFGD_ILB_fines = (SCR_H2SO4_productn_PAF3_preFGD_ILB_fines-NH3_neutrlztn_PAF3_preFGD_ILB_fines)*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100) SCR_H2SO4_emssn_PAF3_preFGD_ILB_fines = 1.22E+01tpy SCR-derived contributn to PAF Unit 3 pre-FGD ILB-coal-fines stack-exit SO3/H2SO4 emissns
PAF Unit 3 pre-FGD Total-coal SCR-derived SO3/H2SO4 Emission Estimate:
Equation (13): SCR_H2SO4_productn_PAF3_preFGD_coal = SCR_H2SO4_productn_PAF3_preFGD_ILB + SCR_H2SO4_productn_PAF3_preFGD_PRB+SCR_H2SO4_productn_PAF3_preFGD_ILB_fines SCR_H2SO4_productn_PAF3_preFGD_coal = 4.85E+02tpy H2SO4
Equation (14): SCR_H2SO4_emssn_PAF3_preFGD_coal = SCR_H2SO4_emssn_PAF3_preFGD_ILB + SCR_H2SO4_emssn_PAF3_preFGD_PRB+SCR_H2SO4_emssn_PAF3_preFGD_ILB_fines SCR_H2SO4_emssn_PAF3_preFGD_coal = 2.68E+02tpy H2SO4 SCR-derived contributn to PAF Unit 3 pre-FGD SO3/H2SO4 stk emissions
Equation (15): SCR_H2SO4_contrl_effncy_PAF3_preFGD_coal = (1-SCR_H2SO4_emssn_PAF3_preFGD_coal/SCR_H2SO4_productn_PAF3_preFGD_coal)*100 SCR_H2SO4_contrl_effncy_PAF3_preFGD_coal = 44.66%
Equation (16): SCR_H2SO4_flue_gas_concen_PAF3_preFGD = SCR_H2SO4_emssn_PAF3_preFGD_coal*(2000 lb/ton)/heat_input_PAF3_preFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr SCR_H2SO4_flue_gas_concen_PAF3_preFGD = 3.74E+00ppmvd at 3% O2 SCR-derived contributn to PAF Unit 3 pre-FGD stack-exit flue-gas SO3/H2SO4 concentration.

PAF Unit 3 Pre-FGD Total Coal-fired SO3/H2SO4 Emission Estimates:
Equation (1): H2SO4_productn_PAF3_preFGD_coal = Blr_H2SO4_productn_PAF3_preFGD_coal+SCR_H2SO4_productn_PAF3_preFGD_coal H2SO4_productn_PAF3_preFGD_coal = 1.51E+03tpy
Equation (2): H2SO4_emssn_PAF3_preFGD_coal = Blr_H2SO4_emssn_PAF3_preFGD_coal+SCR_H2SO4_emssn_PAF3_preFGD_coal H2SO4_emssn_PAF3_preFGD_coal = 9.30E+02tpy PAF Unit 3 pre-FGD coal-fired blr- & SCR-derived contributn to SO3/H2SO4 emissns
Equation (3): H2SO4_emssn_factr_PAF3_preFGD_coal = H2SO4_emssn_PAF3_preFGD_coal*(2000lb/ton)/heat_input_PAF3_preFGD_coal*(TBtu/10^6 MBtu) H2SO4_emssn_factr_PAF3_preFGD_coal = 3.76E-02lb/MBtu
Equation (4): H2SO4_emssn_PAF3_preFGD_coal_hrly = max_heat_input_PAF3*H2SO4_emssn_factr_PAF3_preFGD_coal H2SO4_emssn_PAF3_preFGD_coal_hrly = 4.31E+02lb/unit-hr This value, listed in cell PAF3_preFGD!G29, is based on estimated H2SO4 emssn factr & Title V max heat-input capacity.
Equation (5): H2SO4_contrl_effncy_PAF3_preFGD_coal = (1-H2SO4_emssn_PAF3_preFGD_coal/H2SO4_productn_PAF3_preFGD_coal)*100 H2SO4_contrl_effncy_PAF3_preFGD_coal = 38.21%
Equation (6): H2SO4_stk_gas_concen_PAF3_preFGD_coal = H2SO4_emssn_PAF3_preFGD_coal*(2000 lb/ton)/heat_input_PAF3_preFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr H2SO4_stk_gas_concen_PAF3_preFGD_coal = 1.30E+01ppmvd at 3% O2 PAF Unit 3 pre-FGD total SO3/H2SO4 stack-exit flue-gas concentration.

Page 5 of 16calcs

PAF Unit 3 Post-FGD Coal-fired Boiler Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method):
PAF Unit 3 Post-FGD Illinois Basin (ILB) bituminous coal:
Equation (1): Blr_exit_SOx_PAF3_postFGD_ILB = coal_burn_PAF3_postFGD_ILB*coal_S_PAF_ILB/100*bitum_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_postFGD_ILB = 3.06E+04tpy
Equation (2): Blr_H2SO4_productn_PAF3_postFGD_ILB = Blr_exit_SOx_PAF3_postFGD_ILB*SO3_to_SO2_molar_ratio_HSE/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_postFGD_ILB = 7.50E+02tpy
Equation (3): Blr_H2SO4_emssn_PAF3_postFGD_ILB = Blr_H2SO4_productn_PAF3_postFGD_ILB*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100)*(1-WST_SO3_contrl_effncy_EB/100) Blr_H2SO4_emssn_PAF3_postFGD_ILB = 2.31E+02tpy PAF Unit 3 postFGD ILB-coal boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns
PAF Unit 3 Post-FGD Powder River Basin (PRB) subbituminous coal:
Equation (4): Blr_exit_SOx_PAF3_postFGD_PRB = coal_burn_PAF3_postFGD_PRB*coal_S_PAF_PRB/100*subbit_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_postFGD_PRB = 0.00E+00tpy
Equation (5): Blr_H2SO4_productn_PAF3_postFGD_PRB = Blr_exit_SOx_PAF3_postFGD_PRB*SO3_to_SO2_molar_ratio_sub/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_postFGD_PRB = 0.00E+00tpy
Equation (6): Blr_H2SO4_emssn_PAF3_postFGD_PRB = Blr_H2SO4_productn_PAF3_postFGD_PRB*(1-AH_SO3_contrl_effncy_WC/100)*(1-ESP_SO3_contrl_effncy_WC/100)*(1-WST_SO3_contrl_effncy_WC/100) Blr_H2SO4_emssn_PAF3_postFGD_PRB = 0.00E+00tpy PAF Unit 3 postFGD PRB-coal boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns
PAF Unit 3 Post-FGD Illinois Basin (ILB) bituminous coal fines:
Equation (7): Blr_exit_SOx_PAF3_postFGD_ILB_fines = coal_burn_PAF3_postFGD_ILB_fines*coal_S_PAF_ILB_fines/100*bitum_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF3_postFGD_ILB_fines = 1.81E+03tpy
Equation (8): Blr_H2SO4_productn_PAF3_postFGD_ILB_fines = Blr_exit_SOx_PAF3_postFGD_ILB_fines*SO3_to_SO2_molar_ratio_HSE/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF3_postFGD_ILB_fines = 4.44E+01tpy
Equation (9): Blr_H2SO4_emssn_PAF3_postFGD_ILB_fines = Blr_H2SO4_productn_PAF3_postFGD_ILB_fines*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy/100)*(1-WST_SO3_contrl_effncy_EB/100) Blr_H2SO4_emssn_PAF3_postFGD_ILB_fines = 1.36E+01tpy PAF Unit 3 postFGD ILB coal-fines boiler combustion-derived contributn to SO3/H2SO4 stack-exit emissns

PAF Unit 3 Post-FGD total-coal boiler combustion-derived SO3/H2SO4 emssn:
Equation (10): Blr_H2SO4_productn_PAF3_postFGD_coal = Blr_H2SO4_productn_PAF3_postFGD_ILB+Blr_H2SO4_productn_PAF3_postFGD_PRB+Blr_H2SO4_productn_PAF3_postFGD_ILB_fines Blr_H2SO4_productn_PAF3_postFGD_coal = 7.94E+02tpy
Equation (11): Blr_H2SO4_emssn_PAF3_postFGD_coal = Blr_H2SO4_emssn_PAF3_postFGD_ILB+Blr_H2SO4_emssn_PAF3_postFGD_PRB+Blr_H2SO4_emssn_PAF3_postFGD_ILB_fines Blr_H2SO4_emssn_PAF3_postFGD_coal = 2.44E+02tpy PAF Unit 3 postFGD coal-fired blr combustn-derived contributn to SO3/H2SO4 emissns
Equation (12): Blr_H2SO4_contrl_effncy_PAF3_postFGD = (1-Blr_H2SO4_emssn_PAF3_postFGD_coal/Blr_H2SO4_productn_PAF3_postFGD_coal)*100 Blr_H2SO4_contrl_effncy_PAF3_postFGD = 69.24%
Equation (13): Blr_H2SO4_flue_gas_concen_PAF3_postFGD = Blr_H2SO4_emssn_PAF3_postFGD_coal*(2000 lb/ton)/heat_input_PAF3_postFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr Blr_H2SO4_flue_gas_concen_PAF3_postFGD = 1.20E+01ppmvd at 3% O2 Coal-fired blr combustion-derived contributn to PAF Unit 3 postFGD stk-exit SO3/H2SO4 flue-gas concentration
PAF Unit 3 Post-FGD Selective-catalytic-reduction (SCR) Reactor-Derived SO3/H2SO4 Emission Estimates (HSD Method):
PAF Unit 3 Post-FGD Illinois Basin (ILB) bituminous coal:
Equation (1): SCR_oper_factr_PAF3_postFGD = SCR_operatn_hrs_PAF3_postFGD/blr_operatn_hrs_PAF3_postFGD SCR_oper_factr_PAF3_postFGD = 0.00E+00(dimensionless) Nominal fraction of PAF Unit 3 postFGD coal burn while SCR reactor was in flue-gas path
Equation (2):
max _SCR_oper_factr_PAF3_postFGD = blr_operatn_hrs_PAF3_postFGD/blr_operatn_hrs_PAF3_postFGD
max _SCR_oper_factr_PAF3_postFGD = 1.00E+00 BART (maximum short-term) emissions were estimated using 1.0 for the total SCR operation factor
Equation (3): SCR_H2SO4_productn_PAF3_postFGD_ILB = Blr_exit_SOx_PAF3_postFGD_ILB*SCR_SO2_oxidatn_rate/100*F3_SCR_Other/100*max_SCR_oper_factr_PAF3_postFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_postFGD_ILB = 3.52E+02tpy
Equation (4): SCR_NH3_oper_factr_PAF3_postFGD = SCR_NH3_operatn_hrs_PAF3_postFGD/blr_operatn_hrs_PAF3_postFGD SCR_NH3_oper_factr_PAF3_postFGD = 0.00E+00(dimensionless) Fraction of PAF Unit 3 postFGD coal burn while SCR reactor was in flue-gas path with NH3 inputs
Equation (5): NH3_neutrlztn_PAF3_postFGD_ILB = heat_input_PAF3_postFGD_ILB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_postFGD*flue_gas_factr_dry*20.9/(20.9- flue_gas_O2_concen)*NH3_slip/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_postFGD_ILB = 0.00E+00tpy PAF Unit 3 postFGD ILB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (6): SCR_H2SO4_emssn_PAF3_postFGD_ILB = (SCR_H2SO4_productn_PAF3_postFGD_ILB-NH3_neutrlztn_PAF3_postFGD_ILB)*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100)*(1- WST_SO3_contrl_effncy_EB/100) SCR_H2SO4_emssn_PAF3_postFGD_ILB = 1.08E+02tpy SCR-derived contributn to PAF Unit 3 postFGD ILB stack-exit SO3/H2SO4 emissns
PAF Unit 3 Post-FGD Powder River Basin (PRB) subbituminous coal:
Equation (7): SCR_H2SO4_productn_PAF3_postFGD_PRB = Blr_exit_SOx_PAF3_postFGD_PRB*SCR_SO2_oxidatn_rate/100*F3_SCR_PRB/100*max_SCR_oper_factr_PAF3_postFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_postFGD_PRB = 0.00E+00tpy H2SO4
Equation (8): NH3_neutrlztn_PAF3_postFGD_PRB = heat_input_PAF3_postFGD_PRB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_postFGD*flue_gas_factr_dry*20.9/(20.9- flue_gas_O2_concen)*NH3_slip/10^6/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_postFGD_PRB = 0.00E+00tpy H2SO4 PAF Unit 3 postFGD PRB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (9): SCR_H2SO4_emssn_PAF3_postFGD_PRB = (SCR_H2SO4_productn_PAF3_postFGD_PRB-NH3_neutrlztn_PAF3_postFGD_PRB)*(1-AH_SO3_contrl_effncy_WC/100)*(1-ESP_SO3_contrl_effncy_WC/100)*(1- WST_SO3_contrl_effncy_WC/100) SCR_H2SO4_emssn_PAF3_postFGD_PRB = 0.00E+00tpy H2SO4 SCR-derived contributn to PAF Unit 3 postFGD PRB stack-exit SO3/H2SO4 emissns
PAF Unit 3 Post-FGD Illinois Basin (ILB) bituminous coal fines:
Equation (10): SCR_H2SO4_productn_PAF3_postFGD_ILB_fines = Blr_exit_SOx_PAF3_postFGD_ILB_fines*SCR_SO2_oxidatn_rate/100*F3_SCR_Other/100*max_SCR_oper_factr_PAF3_postFGD*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF3_postFGD_ILB_fines =2.08E+01tpy
Equation (11): NH3_neutrlztn_PAF3_postFGD_ILB_fines = heat_input_PAF3_postFGD_ILB_fines*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF3_postFGD*flue_gas_factr_dry*20.9/(20.9-

Page 6 of 16calcs

flue_gas_O2_concen)*NH3_slip/(molar_vol_STP*293.15/273.15)*H2SO4_mol_wt*(ton/2000 lb) NH3_neutrlztn_PAF3_postFGD_ILB_fines = 0.00E+00tpy PAF Unit 3 postFGD ILB-coal-fines-fired SO3/H2SO4 quantity neutralized by NH3 slip.
Equation (12): SCR_H2SO4_emssn_PAF3_postFGD_ILB_fines = (SCR_H2SO4_productn_PAF3_postFGD_ILB_fines-NH3_neutrlztn_PAF3_postFGD_ILB_fines)*(1-AH_SO3_contrl_effncy_HSE/100)*(1-ESP_SO3_contrl_effncy_HSE/100)*(1- WST_SO3_contrl_effncy_EB/100) SCR_H2SO4_emssn_PAF3_postFGD_ILB_fines = 6.40E+00tpy SCR-derived contributn to PAF Unit 3 postFGD ILB-coal-fines stack-exit SO3/H2SO4 emissns

PAF Unit 3 Post-FGD Total-coal SCR-derived SO3/H2SO4 Emission Estimate:
Equation (13): SCR_H2SO4_productn_PAF3_postFGD_coal = SCR_H2SO4_productn_PAF3_postFGD_ILB + SCR_H2SO4_productn_PAF3_postFGD_PRB+SCR_H2SO4_productn_PAF3_postFGD_ILB_fines SCR_H2SO4_productn_PAF3_postFGD_coal = 3.72E+02tpy H2SO4
Equation (14): SCR_H2SO4_emssn_PAF3_postFGD_coal = SCR_H2SO4_emssn_PAF3_postFGD_ILB + SCR_H2SO4_emssn_PAF3_postFGD_PRB+SCR_H2SO4_emssn_PAF3_postFGD_ILB_fines SCR_H2SO4_emssn_PAF3_postFGD_coal = 1.15E+02tpy H2SO4 SCR-derived contributn to PAF Unit 3 postFGD SO3/H2SO4 stk emissions
Equation (15): SCR_H2SO4_contrl_effncy_PAF3_postFGD_coal = (1-SCR_H2SO4_emssn_PAF3_postFGD_coal/SCR_H2SO4_productn_PAF3_postFGD_coal)*100 SCR_H2SO4_contrl_effncy_PAF3_postFGD_coal = 69.24%
Equation (16): SCR_H2SO4_flue_gas_concen_PAF3_postFGD = SCR_H2SO4_emssn_PAF3_postFGD_coal*(2000 lb/ton)/heat_input_PAF3_postFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr SCR_H2SO4_flue_gas_concen_PAF3_postFGD = 5.62E+00ppmvd at 3% O2 SCR-derived contributn to PAF Unit 3 postFGD stack-exit flue-gas SO3/H2SO4 concentration.

PAF Unit 3 Post-FGD Total Coal-fired SO3/H2SO4 Emission Estimates:
Equation (1): H2SO4_productn_PAF3_postFGD_coal = Blr_H2SO4_productn_PAF3_postFGD_coal+SCR_H2SO4_productn_PAF3_postFGD_coal H2SO4_productn_PAF3_postFGD_coal = 1.17E+03tpy
Equation (2): H2SO4_emssn_PAF3_postFGD_coal = Blr_H2SO4_emssn_PAF3_postFGD_coal+SCR_H2SO4_emssn_PAF3_postFGD_coal H2SO4_emssn_PAF3_postFGD_coal = 3.59E+02tpy PAF Unit 3 postFGD coal-fired blr- & SCR-derived contributn to SO3/H2SO4 emissns
Equation (3): H2SO4_emssn_factr_PAF3_postFGD_coal = H2SO4_emssn_PAF3_postFGD_coal*(2000lb/ton)/heat_input_PAF3_postFGD_coal*(TBtu/10^6 MBtu) H2SO4_emssn_factr_PAF3_postFGD_coal = 5.11E-02lb/MBtu
Equation (4): H2SO4_emssn_PAF3_postFGD_coal_hrly = max_heat_input_PAF3*H2SO4_emssn_factr_PAF3_postFGD_coal H2SO4_emssn_PAF3_postFGD_coal_hrly = 5.85E+02lb/unit-hr This value, listed in cell PAF3_postFGD!G29, is based on estimated H2SO4 emssn factr & Title V max heat-input capacity.
Equation (5): H2SO4_contrl_effncy_PAF3_postFGD_coal = (1-H2SO4_emssn_PAF3_postFGD_coal/H2SO4_productn_PAF3_postFGD_coal)*100 H2SO4_contrl_effncy_PAF3_postFGD_coal = 69.24%
Equation (6): H2SO4_stk_gas_concen_PAF3_postFGD_coal = H2SO4_emssn_PAF3_postFGD_coal*(2000 lb/ton)/heat_input_PAF3_postFGD_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr H2SO4_stk_gas_concen_PAF3_postFGD_coal = 1.76E+01ppmvd at 3% O2 PAF Unit 3 postFGD total SO3/H2SO4 stack-exit flue-gas concentration.

**PA F BART Baseline Ammonia (NH3) Emission Estimates** 
General Input Variables: Value Units Notes Reference
blr_operatn_hrs_PAF1 = 8,029hours/year (hr/yr) PAF Unit 1 boiler total in-service hours 2 blr_operatn_hrs_PAF2 = 7,263hr/yr PAF Unit 2 boiler total in-service hours 2 blr_operatn_hrs_PAF3 = 6,762hr/yr PAF Unit 3 boiler total in-service hours 2 blr_operatn_hrs_PAF3_preFGD = 5,289hr/yr PAF Unit 3 boiler total in-service hours before installation of flue-gas-desulfurization (FGD) scrubber in CY06 2 blr_operatn_hrs_PAF3_postFGD = 1,473hr/yr PAF Unit 3 boiler total in-service hours after installation of FGD scrubber in October 2006 2 SCR_NH3_operatn_hrs_PAF1 = 3,300hr/yr PAF Unit 1 selective-catalytic-reduction (SCR) reactor total in-service hours (with NH3 inputs) 13 SCR_NH3_operatn_hrs_PAF2 = 3,138hr/yr PAF Unit 2 SCR reactor total in-service hours (with NH3 inputs) 13 SCR_NH3_operatn_hrs_PAF3 = 3,304hr/yr PAF Unit 3 SCR reactor total in-service hours (with NH3 inputs) 13 SCR_NH3_operatn_hrs_PAF3_preFGD = 3,304hr/yr PAF Unit 3 SCR reactor total in-service hours (with NH3 inputs) before FGD installation 13 SCR_NH3_operatn_hrs_PAF3_postFGD = 0hr/yr PAF Unit 3 SCR reactor total in-service hours (with NH3 inputs) after FGD installation 13 flue_gas_factr_wet_3%O2 = 12,423wet std ft^3/MBtu Wet flue-gas factor for bitum & subbit. coals at 3% O2 flue-gas concentratn (typical SCR-inlet O2 concentratn) 17 molar_vol = 385.5std ft^3/lb-mol Ideal-gas-law (PV = nRT) molar volume at 20 deg C (68 deg F) 17 NH3_slip = 2ppmv on dry basis (ppmvd) Vendor-guaranteed maximum SCR-exit dry flue-gas NH3 concentration (slip) at 20,000 SCR operating hours 15 NH3_mol_wt = 17.0304lb/lb-mole Ammonia (NH3) molecular weight 11 NH4OH_mol_wt = 35.0456lb/lb-mole Ammonium hydroxide (NH4OH) molecular weight 11 anhydrous_NH3_recpts_truck = 0lb/yr CY06 PAF anhydrous NH3 receipts by truck 18 anhydrous_NH3_recpts_rail = 18,564,920lb/yr CY06 PAF anhydrous NH3 receipts by rail 18 unloading_emssn_factr_truck_NH3 = 1.38E-05lb/lb NH3 delivery Emission factor estimated from pipe/hose dimensions/volumes for truck deliveries at TVA's Paradise Fossil Plant 19 unloading_emssn_factr_rail_NH3 = 1.05E-07lb/lb NH3 delivery Emission factor estimated from pipe/hose dimensions/volumes for rail deliveries at TVA's Paradise Fossil Plant 19 T1_AH_EB = 0.001dimensionless Penetration of gaseous NH3 through air heater (AH) in units burning Eastern bituminous (EB) coal 17 T1_CS_ESP_EB = 1.00dimensionless Penetration of gaseous NH3 through cold-side electrostatic precipitator (CS ESP) in units burning EB coal 17 T1_BF_EB = 0.10dimensionless Penetration of gaseous NH3 through bagfilter (BF) in units burning EB coal 17 T1_WFGD_EB = 0.01dimensionless Penetration of gaseous NH3 through wet flue-gas-desulfurization (WFGD) scrubber in units burning EB coal 17 T1_DFGD_BF_EB = 0.025dimensionless Penetration of gaseous NH3 through dry FGD scrubber with bagfilter (DFGD_BF) in units burning EB coal 17 T1_AH_PRB = 0.75dimensionless Penetration of gaseous NH3 through AH in units burning PRB subbituminous coal 17 T1_POST_APH_FGC_PRB = 0.35dimensionless Penetration of gaseous NH3 through post-AH SO3 flue-gas-conditioning (FGC) in units burning PRB subbit. coal 17 T1_CS_ESP_PRB = 1.00dimensionless Penetration of gaseous NH3 through CS ESP in units burning PRB subbituminous coal 17 T1_BF_PRB = 0.95dimensionless Penetration of gaseous NH3 through BF in units burning PRB subbituminous coal 17 T1_WFGD_PRB = 0.01dimensionless Penetration of gaseous NH3 through WFGD scrubber in units burning PRB subbituminous coal 17 T1_DFGD_BF_PRB = 0.2375dimensionless Penetration of gaseous NH3 through DFGD scrubber with BF in units burning PRB subbituminous coal 17 T1_AH_RMB = 0.75dimensionless Penetration of gaseous NH3 through AH in units burning Rocky Mtn bituminous (RMB) coal 20 T1_POST_APH_FGC_RMB = 0.35dimensionless Penetration of gaseous NH3 through post-AH SO3 FGC in units burning RMB coal 20 T1_CS_ESP_RMB = 1.00dimensionless Penetration of gaseous NH3 through CS ESP in units burning RMB coal 20 T1_BF_RMB = 0.95dimensionless Penetration of gaseous NH3 through BF in units burning RMB coal 20 T1_WFGD_RMB = 0.01dimensionless Penetration of gaseous NH3 through WFGD scrubber in units burning RMB coal 20 T1_DFGD_BF_RMB = 0.2375dimensionless Penetration of gaseous NH3 through DFGD scrubber with BF in units burning RMB coal 20 T5_AH_EB = 0.75dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning EB coal 17 T5_AH_FGC_PRB = 0.60dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning PRB coal w/ SO3 FGC 17 T5_AH_PRB = 0.20dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning PRB coal 17 T5_AH_FGC_RMB = 0.60dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning RMB coal w/ SO3 FGC 20 T5_AH_RMB = 0.20dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning RMB coal 20 T6_CS_ESP = 0.01dimensionless Penetration of NH3 adsorbed on particles (and NH4 salts) through CS ESP in units burning any coal 17 T6_BF = 0.002dimensionless Penetration of NH3 adsorbed on particles (and NH4 salts) through bagfilter in units burning any coal 17 T6_DFGD = 1.00dimensionless Penetration of NH3 adsorbed on particles (and NH4 salts) through dry FGD scrubber in units burning any coal 17 T6_WFGD = 0.50dimensionless Penetration of NH3 adsorbed on particles (and NH4 salts) through wet FGD scrubber in units burning any coal 17 T6_WFGD_PAF1_2 = 0.056dimensionless CY06 penetration of filterable particulate matter (PM_fil) through PAF Units 1-2 venturi wet FGD scrubbers T7_AH_EB = 0.0490dimensionless Capture of NH3 adsorbed on particles (and NH4 salts) by AH in units burning EB coal 17 T7_AH_PRB = 0.005dimensionless Capture of NH3 adsorbed on particles (and NH4 salts) by AH in units burning PRB coal 17 T7_AH_RMB = 0.005dimensionless Capture of NH3 adsorbed on particles (and NH4 salts) by AH in units burning RMB coal 20 E1_AH_EB_air = 0.20dimensionless Fugitive air-release fraction of NH3 adsorbed on particles (& NH4 salts) captured by AH in units burning EB coal 17 E1_CS_ESP_EB_air = 0.10dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by CS ESP in units burning EB coal 17 E1_BF_EB_air = 0.10dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by BF in units burning EB coal 17 E1_WFGD_EB_air = 0.20dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by WFGD in units burning EB coal 17 E1_DFGD_BF_EB_air = 0.10dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by DFGD/BF in units burning EB coal 17 E1_AH_PRB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by AH in units burning PRB coal 17 E1_CS_ESP_PRB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by CS ESP in units burning PRB coal 17 E1_BF_PRB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by BF in units burning PRB coal 17 E1_WFGD_PRB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by WFGD in units burning PRB coal 17 E1_DFGD_BF_PRB_air = 0.10dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by DFGD/BF in units burning PRB coal 17 E1_AH_RMB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by AH in units burning RMB coal 20

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E1_CS_ESP_RMB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by CS ESP in units burning RMB coal 20 E1_BF_RMB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by BF in units burning RMB coal 20 E1_WFGD_RMB_air = 0.95dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by WFGD in units burning RMB coal 20 E1_DFGD_BF_RMB_air = 0.10dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by DFGD/BF in units burning RMB coal 20 aqueous_NH3_rcpts = 47,260lb/yr PAF plant-total boiler-water-treatment (BWT) aqueous NH3 receipts 18 aqueous_NH4OH_wt_fractn = 35% Unless otherwise indicated, presumed weight percent NH4OH in BWT aqueous NH3 solution BWT_tank_NH3_air = 0.64dimensionless Fugitive air-release fractn of NH3 in BWT solution disposed to open-air tank 17 BWT_pond_NH3_air = 0.10dimensionless Fugitive air-release fractn of NH3 in BWT solution disposed to ash pond (PAF uses ash pond for BWTdisposal) 17 FA_productn = 143,037tons/yr (tpy) PAF flyash production 5 FA_dry_sales = 0tpy No CY06 PAF dry flyash sales (e.g., off-site cement substitute in ready-mix concrete) 5
Selective-catalytic-reduction (SCR) Reactor-Derived Stack NH3 (& Ammonium Salt) Emission Estimates:
PAF Illinois Basin (ILB) bituminous coal:
Equation (1): SD = FA_dry_sales/FA_productn SD = 0.00dimensionless Fraction of fly ash captured dry and sold/transferred offsite
Equation (2): coal_burn_PAF1_ILB_SCR = coal_burn_PAF1_ILB*SCR_NH3_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 coal_burn_PAF1_ILB_SCR = 798,299tpy PAF Unit 1 ILB coal burn while SCR reactor was receiving NH3 inputs
Equation (3): coal_burn_PAF2_ILB_SCR = coal_burn_PAF2_ILB*SCR_NH3_operatn_hrs_PAF2/blr_operatn_hrs_PAF2 coal_burn_PAF2_ILB_SCR = 750,588tpy
Equation (4): coal_burn_PAF1_2_ILB_SCR = coal_burn_PAF1_ILB_SCR+coal_burn_PAF2_ILB_SCR coal_burn_PAF1_2_ILB_SCR = 1,548,887tpy
Equation (5): flue_gas_flow_PAF1_2_ILB_SCR = coal_burn_PAF1_2_ILB_SCR*(2000lb/ton)*coal_heat_PAF_ILB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF1_2_ILB_SCR = 4.52E+11std ft^3/yr
Equation (6): SCR_exit_NH3_mass_rate_PAF1_2_ILB = flue_gas_flow_PAF_1_2_ILB_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF1_2_ILB = 3.67E+04lb/yr
Equation (7): NH3_stk_emssn_PAF1_2_ILB = SCR_exit_NH3_mass_rate_PAF1_2_ILB*T1_AH_EB*T1_WFGD_EB NH3_stk_emssn_PAF1_2_ILB = 3.67E-01lb/yr
Equation (8): NH4_salt_stk_emssn_PAF1_2_ILB = SCR_exit_NH3_mass_rate_PAF1_2_ILB*T5_AH_EB*T6_WFGD_PAF1_2 NH4_salt_stk_emssn_PAF1_2_ILB = 1.53E+03lb/yr NH4-salt mass expressed as NH3 equivalent, but subsumed within total PM emissions & not separately reported.
Equation (9): SCR_NH3_fugitive_emssn_PAF1_2_ILB = SCR_exit_NH3_mass_rate_PAF1_2_ILB*(T7_AH_EB*E1_AH_EB_air+T1_AH_EB*(1-T1_WFGD_EB)*E1_WFGD_EB_air+T5_AH_EB*(1-T6_WFGD_PAF1_2)*E1_WFGD_EB_air) SCR_NH3_fugitive_emssn_PAF1_2_ILB = 5.57E+03lb/yr
Equation (10): coal_burn_PAF3_preFGD_ILB_SCR = coal_burn_PAF3_preFGD_ILB*SCR_NH3_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD coal_burn_PAF3_preFGD_ILB_SCR = 461,502tpy
Equation (11): flue_gas_flow_PAF3_preFGD_ILB_SCR = coal_burn_PAF3_preFGD_ILB_SCR*(2000lb/ton)*coal_heat_PAF_ILB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF3_preFGD_ILB_SCR = 1.35E+11std ft^3/yr
Equation (12): SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB = flue_gas_flow_PAF3_preFGD_ILB_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB = 1.09E+04lb/yr
Equation (13): NH3_stk_emssn_PAF3_preFGD_ILB = SCR_exit_NH3_mass_rate_PAF3_ILB*T1_AH_EB*T1_CS_ESP_EB NH3_stk_emssn_PAF3_preFGD_ILB = 1.09E+01lb/yr
Equation (14): NH4_salt_stk_emssn_PAF3_preFGD_ILB = SCR_exit_NH3_mass_rate_PAF3_ILB*T5_AH_EB*T6_CS_ESP NH4_salt_stk_emssn_PAF3_preFGD_ILB = 8.21E+01lb/yr
Equation (15): SCR_NH3_fugitive_emssn_PAF3_preFGD_ILB = SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB*(T7_AH_EB*E1_AH_EB_air+T5_AH_EB*[1-T6_CS_ESP]*[1-SD]*E1_CS_ESP_EB_air) SCR_NH3_fugitive_emssn_PAF3_preFGD_ILB = 9.20E+02lb/yr
PAF Powder River Basin (PRB) subbituminous coal:
Equation (1): coal_burn_PAF1_PRB_SCR = coal_burn_PAF1_PRB*SCR_NH3_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 coal_burn_PAF1_PRB_SCR = 13,236tpy
Equation (2): coal_burn_PAF2_PRB_SCR = coal_burn_PAF2_PRB*SCR_NH3_operatn_hrs_PAF2/blr_operatn_hrs_PAF2 coal_burn_PAF2_PRB_SCR = 12,445tpy
Equation (3): coal_burn_PAF1_2_PRB_SCR = coal_burn_PAF1_PRB_SCR+coal_burn_PAF2_PRB_SCR coal_burn_PAF1_2_PRB_SCR = 25,681tpy
Equation (4): flue_gas_flow_PAF1_2_PRB_SCR = coal_burn_PAF1_2_PRB_SCR*(2000lb/ton)*coal_heat_PAF_PRB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF1_2_PRB_SCR = 5.65E+09std ft^3/yr
Equation (5): SCR_exit_NH3_mass_rate_PAF1_2_PRB = flue_gas_flow_PAF_1_2_PRB_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF1_2_PRB = 4.59E+02lb/yr
Equation (6): NH3_stk_emssn_PAF1_2_PRB = SCR_exit_NH3_mass_rate_PAF1_2_PRB*T1_AH_PRB*T1_WFGD_PRB NH3_stk_emssn_PAF1_2_PRB = 3.44E+00lb/yr
Equation (7): NH4_salt_stk_emssn_PAF1_2_PRB = SCR_exit_NH3_mass_rate_PAF1_2_PRB*T5_AH_PRB*T6_WFGD_PAF1_2 NH4_salt_stk_emssn_PAF1_2_PRB = 5.10E+00lb/yr NH4-salt mass expressed as NH3 equivalent, but subsumed within total PM emissions & not separately reported.

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Equation (8): SCR_NH3_fugitive_emssn_PAF1_2_PRB = SCR_exit_NH3_mass_rate_PAF1_2_PRB*(T7_AH_PRB*E1_AH_PRB_air+T1_AH_PRB*(1-T1_WFGD_PRB)*E1_WFGD_PRB_air+T5_AH_PRB*(1-T6_WFGD_PAF1_2)*E1_WFGD_PRB_air) SCR_NH3_fugitive_emssn_PAF1_2_PRB = 4.08E+02lb/yr
Equation (9): coal_burn_PAF3_preFGD_PRB_SCR = coal_burn_PAF3_preFGD_PRB*SCR_NH3_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD coal_burn_PAF3_preFGD_PRB_SCR = 1,119,099tpy
Equation (10): flue_gas_flow_PAF3_preFGD_PRB_SCR = coal_burn_PAF3_preFGD_PRB_SCR*(2000lb/ton)*coal_heat_PAF_PRB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF3_preFGD_PRB_SCR = 2.46E+11std ft^3/yr
Equation (11): SCR_exit_NH3_mass_rate_PAF3_preFGD_PRB = flue_gas_flow_PAF3_preFGD_PRB_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF3_preFGD_PRB = 2.00E+04lb/yr
Equation (12): NH3_stk_emssn_PAF3_preFGD_PRB = SCR_exit_NH3_mass_rate_PAF3_preFGD_PRB*T1_AH_PRB*T1_CS_ESP_PRB NH3_stk_emssn_PAF3_preFGD_PRB = 1.50E+04lb/yr
Equation (13): NH4_salt_stk_emssn_PAF3_preFGD_PRB = SCR_exit_NH3_mass_rate_PAF3_preFGD_PRB*T5_AH_PRB*T6_CS_ESP NH4_salt_stk_emssn_PAF3_preFGD_PRB = 4.00E+01lb/yr
Equation (14): SCR_NH3_fugitive_emssn_PAF3_preFGD_PRB = SCR_exit_NH3_mass_rate_PAF3_preFGD_PRB*(T7_AH_PRB*E1_AH_PRB_air+T5_AH_PRB*[1-T6_CS_ESP]*[1-SD]*E1_CS_ESP_PRB_air) SCR_NH3_fugitive_emssn_PAF3_preFGD_PRB = 3.85E+03lb/yr
PAF Illinois Basin (ILB) bituminous coal fines:
Equation (1): coal_burn_PAF1_ILB_fines_SCR = coal_burn_PAF1_ILB_fines*SCR_NH3_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 coal_burn_PAF1_ILB_fines_SCR = 15,718tpy PAF Unit 1 ILB coal burn while SCR reactor was receiving NH3 inputs
Equation (2): coal_burn_PAF2_ILB_fines_SCR = coal_burn_PAF2_ILB_fines*SCR_NH3_operatn_hrs_PAF2/blr_operatn_hrs_PAF2 coal_burn_PAF2_ILB_fines_SCR = 14,778tpy
Equation (3): coal_burn_PAF1_2_ILB_fines_SCR = coal_burn_PAF1_ILB_fines_SCR+coal_burn_PAF2_ILB_fines_SCR coal_burn_PAF1_2_ILB_fines_SCR = 30,496tpy
Equation (4): flue_gas_flow_PAF1_2_ILB_fines_SCR = coal_burn_PAF1_2_ILB_fines_SCR*(2000lb/ton)*coal_heat_PAF_ILB_fines*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF1_2_ILB_fines_SCR = 5.06E+09std ft^3/yr
Equation (5): SCR_exit_NH3_mass_rate_PAF1_2_ILB_fines = flue_gas_flow_PAF_1_2_ILB_fines_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF1_2_ILB_fines = 4.11E+02lb/yr
Equation (6): NH3_stk_emssn_PAF1_2_ILB_fines = SCR_exit_NH3_mass_rate_PAF1_2_ILB_fines*T1_AH_EB*T1_WFGD_EB NH3_stk_emssn_PAF1_2_ILB_fines = 4.11E-03lb/yr
Equation (7): NH4_salt_stk_emssn_PAF1_2_ILB_fines = SCR_exit_NH3_mass_rate_PAF1_2_ILB_fines*T5_AH_EB*T6_WFGD_PAF1_2 NH4_salt_stk_emssn_PAF1_2_ILB_fines = 1.71E+01lb/yr NH4-salt mass expressed as NH3 equivalent, but subsumed within total PM emissions & not separately reported.
Equation (8): SCR_NH3_fugitive_emssn_PAF1_2_ILB_fines = SCR_exit_NH3_mass_rate_PAF1_2_ILB_fines*(T7_AH_EB*E1_AH_EB_air+T1_AH_EB*(1-T1_WFGD_EB)*E1_WFGD_EB_air+T5_AH_EB*(1-T6_WFGD_PAF1_2)*E1_WFGD_EB_air) SCR_NH3_fugitive_emssn_PAF1_2_ILB_fines = 6.23E+01lb/yr
Equation (9): coal_burn_PAF3_preFGD_ILB_fines_SCR = coal_burn_PAF3_preFGD_ILB_fines*SCR_NH3_operatn_hrs_PAF3_preFGD/blr_operatn_hrs_PAF3_preFGD coal_burn_PAF3_preFGD_ILB_fines_SCR = 18,150tpy
Equation (10): flue_gas_flow_PAF3_preFGD_ILB_fines_SCR = coal_burn_PAF3_preFGD_ILB_fines_SCR*(2000lb/ton)*coal_heat_PAF_ILB_fines*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF3_preFGD_ILB_fines_SCR = 3.01E+09std ft^3/yr
Equation (11): SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB_fines = flue_gas_flow_PAF3_preFGD_ILB_fines_SCR*NH3_slip/10^6*flue_gas_factr_dry/flue_gas_factr_wet_0%O2/molar_vol*NH3_mol_wt SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB_fines = 2.44E+02lb/yr
Equation (12): NH3_stk_emssn_PAF3_preFGD_ILB_fines = SCR_exit_NH3_mass_rate_PAF3_ILB_fines*T1_AH_EB*T1_CS_ESP_EB NH3_stk_emssn_PAF3_preFGD_ILB_fines = 2.44E-01lb/yr
Equation (13): NH4_salt_stk_emssn_PAF3_preFGD_ILB_fines = SCR_exit_NH3_mass_rate_PAF3_ILB_fines*T5_AH_EB*T6_CS_ESP NH4_salt_stk_emssn_PAF3_preFGD_ILB_fines = 1.83E+00lb/yr
Equation (14): SCR_NH3_fugitive_emssn_PAF3_preFGD_ILB_fines = SCR_exit_NH3_mass_rate_PAF3_preFGD_ILB_fines*(T7_AH_EB*E1_AH_EB_air+T5_AH_EB*[1-T6_CS_ESP]*[1-SD]*E1_CS_ESP_EB_air) SCR_NH3_fugitive_emssn_PAF3_preFGD_ILB_fines = 2.05E+01lb/yr
PAF Unit 1 Coal-fired Boiler-Total SCR-Reactor-Derived Stack NH3 (& Ammonium Salt) Emission Estimates:
Equation (1): NH3_stk_emssn_PAF1_coal = (NH3_stk_emssn_PAF1_2_ILB+NH3_stk_emssn_PAF1_2_PRB+NH3_stk_emssn_PAF1_2_ILB_fines)*coal_burn_PAF1_ILB_SCR/coal_burn_PAF1_2_ILB_SCR*(ton/2000 lb) NH3_stk_emssn_PAF1_coal = 9.82E-04tons/yr (tpy) CY06 PAF Unit 1 gaseous NH3 stack emissions, listed in cell F30 of "PAF1" worksheet
Equation (2): NH3_emssn_factr_PAF1_coal = NH3_stk_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) NH3_emssn_factr_PAF1_coal = 4.20E-08lb/MBtu
Equation (3): NH3_emssn_PAF1_coal_hrly = max_heat_input_PAF1*NH3_emssn_factr_PAF1_coal NH3_emssn_PAF1_coal_hrly = 2.92E-04lb/unit-hr This value, listed in cell PAF1!G30, is based on estimated NH3 emssn factr & Title V max heat-input capacity.
Equation (4): NH4_salt_stk_emssn_PAF1_coal = (NH4_salt_stk_emssn_PAF1_2_ILB+NH4_salt_stk_emssn_PAF1_2_PRB+NH4_salt_stk_emssn_PAF1_2_ILB_fines)*coal_burn_PAF1_ILB_SCR/coal_burn_PAF1_2_ILB_SCR*(ton/2000 lb) NH4_salt_stk_emssn_PAF1_coal = 4.00E-01tpy Ammonium (NH4)-salt stack emissions are subsumed within total PM emissions & are not separately reported.
PAF Plant-Total Fugitive-Air NH3 Emission Estimates:
Equation (1): SCR_NH3_fugitive_emssn_PAF = SCR_NH3_fugitive_emssn_PAF1_2_ILB+SCR_NH3_fugitive_emssn_PAF1_2_PRB+SCR_NH3_fugitive_emssn_PAF3_ILB+SCR_NH3_fugitive_emssn_PAF3_PRB+ SCR_NH3_fugitive_emssn_PAF1_2_ILB_fines+SCR_NH3_fugitive_emssn_PAF3_preFGD_ILB_fines SCR_NH3_fugitive_emssn_PAF = 1.08E+04lb/yr

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Equation (2): Unloading_NH3_fugitive_emssn_PAF = anhydrous_NH3_recpts_truck*unloading_emssn_factr_truck_NH3+anhydrous_NH3_recpts_rail*unloading_emssn_factr_rail Unloading_NH3_fugitive_emssn_PAF = 1.95E+00lb/yr
Equation (3): BWT_NH3_fugitive_emssn_PAF = aqueous_NH3_rcpts*aqueous_NH4OH_wt_fractn/100*NH3_mol_wt/NH4OH_mol_wt*BWT_pond_NH3_air BWT_NH3_fugitive_emssn_PAF = 8.04E+02lb/yr
Equation (4): NH3_fugitive_emssn_PAF = (SCR_NH3_fugitive_emssn_PAF+Unloading_NH3_fugitive_emssn_PAF+BWT_NH3_fugitive_emssn_PAF)*(ton/2000 lb) NH3_fugitive_emssn_PAF = 5.82E+00tpy CY06 PAF plant-total NH3 fugitive air emissions, listed in cell W22 of "air" worksheet

**PA F Unit 1 Routine Coal-fired Trace-Element Hazardous-Air-Pollutant (HAP) Emission Estimates:** 
Trace-element emission estimates were derived from EPRI's Emission Factor Handbook (EFH). Lead (Pb) is typical of PM trace elements; hydrogen chloride (HCl) and mercury (Hg) are examples of gaseous trace-element HAP with significantly different emission-estimation methodologies.

Pb Emission Estimates:
PAF Unit 1 Illinois Basin (ILB) bituminous coal:
Equation (1): Pb_emssn_factr_PAF1_ILB = 3.4*(Pb_in_ILB_mass*(1-coal_H2O_PAF_ILB/100)*(100/coal_ash_PAF_ILB)*PM_fil_emssn_factr_PAF1_coal)^0.80 Pb_emssn_factr_PAF1_ILB = 3.00E+01lb/10^12 Btu (TBtu) = EFH Median Pb Emission Correlation Estimate 10
Equation (2): Pb_in_ILB_energy = Pb_in_ILB_mass*(kg/10^6 mg)/coal_heat_PAF_ILB*(1-coal_H2O_PAF_ILB/100)*(10^12 Btu/TBtu) Pb_in_ILB_energy = 1.06E+03lb/TBtu
Equation (3): Pb_contrl_effncy_PAF1_ILB = (1-Pb_emssn_factr_PAF1_ILB/Pb_in_ILB_energy)*100% Pb_contrl_effncy_PAF1_ILB = 97.18% = PAF Unit 1 Boiler/FGD contrl effncy for Pb in ILB coal
Equation (4): Pb_emssn_PAF1_ILB = Pb_emssn_factr_PAF1_ILB*heat_input_PAF1_ILB*(ton/2000 lb) Pb_emssn_PAF1_ILB = 6.84E-01tpy This value is listed in cell F41 of "PAF1_ILB" worksheet (PAF1_ILB!F41).
PAF Unit 1 Powder River Basin (PRB) subbituminous coal:
Equation (5): Pb_emssn_factr_PAF1_PRB = 3.4*(Pb_in_PRB_mass*(1-coal_H2O_PAF_PRB/100)*(100/coal_ash_PAF_PRB)*PM_fil_emssn_factr_PAF1_coal)^0.80 Pb_emssn_factr_PAF1_PRB = 1.15E+01lb/TBtu = EFH Median Pb Emission Correlation Estimate 10
Equation (6): Pb_in_PRB_energy = Pb_in_PRB_mass*(kg/10^6 mg)/coal_heat_PAF_PRB*(1-coal_H2O_PAF_PRB/100)*(10^12 Btu/TBtu) Pb_in_PRB_energy = 2.65E+02lb/TBtu
Equation (7): Pb_contrl_effncy_PAF1_PRB = (1-Pb_emssn_factr_PAF1_PRB/Pb_in_PRB_energy)*100% Pb_contrl_effncy_PAF1_PRB = 95.66% = PAF Unit 1 Boiler/FGD contrl effncy for Pb in PRB coal
Equation (8): Pb_emssn_PAF1_PRB = Pb_emssn_factr_PAF1_PRB*heat_input_PAF1_PRB*(ton/2000 lb) Pb_emssn_PAF1_PRB = 3.28E-03tpy This value is listed in cell F41 of "PAF1_PRB" worksheet (PAF1_PRB!F41).
PAF Unit 1 Illinois Basin (ILB) bituminous coal fines:
Equation (9): Pb_emssn_factr_PAF1_ILB_fines = 3.4*(Pb_in_ILB_fines_mass*(1-coal_H2O_PAF_ILB_fines/100)*(100/coal_ash_PAF_ILB_fines)*PM_fil_emssn_factr_PAF1_coal)^0.80 Pb_emssn_factr_PAF1_ILB_fines = 2.04E+01lb/TBtu = EFH Median Pb Emission Correlation Estimate
Equation (10): Pb_in_ILB_fines_energy = Pb_in_ILB_fines_mass*(kg/10^6 mg)/coal_heat_PAF_ILB_fines*(1-coal_H2O_PAF_ILB_fines/100)*(10^12 Btu/TBtu) Pb_in_ILB_fines_energy = 3.64E+03lb/TBtu
Equation (11): Pb_contrl_effncy_PAF1_ILB_fines = (1-Pb_emssn_factr_PAF1_ILB_fines/Pb_in_ILB_fines_energy)*100% Pb_contrl_effncy_PAF1_ILB_fines = 99.44% = PAF Unit 1 Boiler/FGD contrl effncy for Pb in ILB coal fines
Equation (12): Pb_emssn_PAF1_ILB_fines = Pb_emssn_factr_PAF1_ILB_fines*heat_input_PAF1_ILB_fines*(ton/2000 lb) Pb_emssn_PAF1_ILB_fines = 5.21E-03tpy This value is listed in cell F41 of "PAF1_ILB_fines" worksheet (PAF1_ILB_fines!F41).

PAF Unit 1 total-coal Pb emssn:
Equation (13): Pb_emssn_PAF1_coal = Pb_emssn_PAF1_ILB+Pb_emssn_PAF1_PRB+Pb_emssn_PAF1_ILB_fines Pb_emssn_PAF1_coal = 6.93E-01tpy This value is listed in cell PAF1!F41 and in cell B35 of "air" worksheet.
Equation (14): Pb_in_coal_energy_PAF1 = (Pb_in_ILB_energy*heat_input_PAF1_ILB+Pb_in_PRB_energy*heat_input_PAF1_PRB+Pb_in_ILB_fines_energy*heat_input_PAF1_ILB_fines)/heat_input_PAF1_coal Pb_in_coal_energy_PAF1 = 1.08E+03lb/TBtu
Equation (15): Pb_emssn_factr_PAF1_coal = Pb_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal Pb_emssn_factr_PAF1_coal = 2.96E+01lb/TBtu
Equation (16): Pb_emssn_PAF1_coal_hrly = max_heat_input_PAF1*Pb_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) Pb_emssn_PAF1_coal_hrly = 2.06E-01lb/unit-hr This value, listed in cell PAF1!G41, is based on estimated Pb emssn factr & Title V max heat-input capacity.
Equation (17): Pb_contrl_effncy_PAF1 = (1-Pb_emssn_factr_PAF1_coal/Pb_in_coal_energy_PAF1)*100 Pb_contrl_effncy_PAF1 = 97.26% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E41 in "PAF1" wksheet)
Note that coal-region weighted-avg. boiler/FGD coal trace-element control efficiencies (e.g., cell E41 in "PAF1" wksheet for Pb) were used to estimate alternate-fuel contol efficiencies.

HCl Emission Estimates:
PAF Unit 1 Illinois Basin (ILB) bituminous coal:
Equation (1): Cl_in_ILB_energy = Cl_in_ILB_mass*(kg/10^6 mg)/coal_heat_PAF_ILB*(10^12 Btu/TBtu) Cl_in_ILB_energy = 5.12E+04lb Cl/TBtu
Equation (2): HCl_emssn_factr_PAF1_ILB = Cl_in_ILB_energy*(1-Cl_contrl_effncy_FGD/100)*HCl_mol_wt/Cl_mol_wt HCl_emssn_factr_PAF1_ILB = 1.58E+03lb HCl/TBtu = EFH Recommended HCl Emission Factor Estimate 10
Equation (3): HCl_emssn_PAF1_ILB = HCl_emssn_factr_PAF1_ILB*heat_input_PAF1_ILB*(ton/2000 lb) HCl_emssn_PAF1_ILB = 3.61E+01tpy This value is listed in cell F52 of "PAF1_ILB" worksheet (PAF1_ILB!F52).
PAF Unit 1 Powder River Basin (PRB) subbituminous coal:
Equation (4):

Page 10 of 16calcs

Cl_in_PRB_energy = Cl_in_PRB_mass*(kg/10^6 mg)/coal_heat_PAF_PRB*(10^12 Btu/TBtu) Cl_in_PRB_energy = 5.65E+03lb Cl/TBtu
Equation (5): HCl_emssn_factr_PAF1_PRB = Cl_in_PRB_energy*(1-Cl_contrl_effncy_FGD/100)*HCl_mol_wt/Cl_mol_wt HCl_emssn_factr_PAF1_PRB = 1.74E+02lb HCl/TBtu = EFH Recommended HCl Emission Factor Estimate 10
Equation (6): HCl_emssn_PAF1_PRB = HCl_emssn_factr_PAF1_PRB*heat_input_PAF1_PRB*(ton/2000 lb) HCl_emssn_PAF1_PRB = 4.97E-02tpy This value is listed in cell PAF1_PRB!F52.
PAF Unit 1 Illinois Basin (ILB) bituminous coal fines:
Equation (7): Cl_in_ILB_fines_energy = Cl_in_ILB_fines_mass*(kg/10^6 mg)*(1-coal_H2O_PAF_ILB_fines/100)/coal_heat_PAF_ILB_fines*(10^12 Btu/TBtu) Cl_in_ILB_fines_energy = 1.80E+04lb Cl/TBtu
Equation (8): HCl_emssn_factr_PAF1_ILB_fines = Cl_in_ILB_fines_energy*(1-Cl_contrl_effncy_FGD/100)*HCl_mol_wt/Cl_mol_wt HCl_emssn_factr_PAF1_ILB_fines = 5.55E+02lb HCl/TBtu = EFH Recommended HCl Emission Factor Estimate
Equation (9): HCl_emssn_PAF1_ILB_fines = HCl_emssn_factr_PAF1_ILB_fines*heat_input_PAF1_ILB_fines*(ton/2000 lb) HCl_emssn_PAF1_ILB_fines = 1.42E-01tpy This value is listed in cell PAF1_ILB_fines!F52.

PAF Unit 1 total-coal HCl emssn:
Equation (10): HCl_emssn_PAF1_coal = HCl_emssn_PAF1_ILB+HCl_emssn_PAF1_PRB+HCl_emssn_PAF1_ILB_fines HCl_emssn_PAF1_coal = 3.63E+01tpy This value is listed in cell PAF1!F52 and in air!B30.
Equation (11): Cl_in_coal_energy_PAF = (Cl_in_ILB_energy*heat_input_PAF1_ILB+Cl_in_PRB_energy*heat_input_PAF1_PRB+Cl_in_ILB_fines_energy*heat_input_PAF1_ILB_fines)/heat_input_PAF1_coal Cl_in_coal_energy_PAF = 5.03E+04lb/TBtu
Equation (12): HCl_emssn_factr_uncontrolld_PAF_coal = Cl_in_coal_energy_PAF*HCl_mol_wt/Cl_mol_wt HCl_emssn_factr_uncontrolld_PAF_coal = 5.17E+04lb/TBtu
Equation (13): HCl_emssn_factr_PAF1_coal = HCl_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal HCl_emssn_factr_PAF1_coal = 1.55E+03lb/TBtu
Equation (14): HCl_emssn_PAF1_coal_hrly = max_heat_input_PAF1*HCl_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) HCl_emssn_PAF1_coal_hrly = 1.08E+01lb/unit-hr This value, listed in cell PAF1!G52, is based on estimated HCl emssn factr & Title V max heat-input capacity.
Equation (15): HCl_contrl_effncy_PAF1_coal = (1-HCl_emssn_factr_PAF1_coal/HCl_emssn_factr_uncontrolld_PAF_coal)*100 HCl_contrl_effncy_PAF1_coal = 97.00% PAF Unit 1 coal-region weighted-avg. boiler/FGD total-coal HCl control efficiency
Hg Emission Estimates:
PAF Unit 1 Illinois Basin (ILB) bituminous coal:
Equation (1): Hg_in_ILB_energy = Hg_in_ILB_mass*(kg/10^6 mg)/coal_heat_PAF_ILB*(1-coal_H2O_PAF_ILB/100)*(10^12 Btu/TBtu) Hg_in_ILB_energy = 6.06E+00lb/TBtu
Equation (2): Hg_contrl_effncy_PAF1_ILB_SCR = Hg_removal_effncy_SCR_FGDW_bitum Hg_contrl_effncy_PAF1_ILB_SCR = 86% Hg removal efficiency for Eastern-bitum-fired boilers w/selective-catalytic-reduction (SCR) reactor & FGD scrubber 10
Equation (3): Hg_contrl_effncy_PAF1_ILB_SCR_bypass = (Hg_removal_multiplier_FGDW*ln(Cl_in_coal_ILB/(1-coal_H2O_PAF_ILB/100))+Hg_removal_constant_FGDW)*100% Hg_contrl_effncy_PAF1_ILB_SCR_bypass = 18.60% EFH Boiler/FGD contrl effncy for Hg in ILB coal (when flue-gas path bypasses SCR reactor) 10
Equation (4): Hg_contrl_effncy_PAF1_ILB = Hg_contrl_effncy_PAF1_ILB_SCR*SCR_oper_factr_PAF1+Hg_contrl_effncy_PAF1_ILB_SCR_bypass*(1-SCR_oper_factr_PAF1) Hg_contrl_effncy_PAF1_ILB = 46.37%
Equation (5): Hg_emssn_factr_PAF1_ILB = Hg_in_ILB_energy*(1-Hg_contrl_effncy_PAF1_ILB/100) Hg_emssn_factr_PAF1_ILB = 3.25E+00lb/TBtu
Equation (6): Hg_emssn_PAF1_ILB = Hg_emssn_factr_PAF1_ILB*heat_input_PAF1_ILB*(ton/2000 lb) Hg_emssn_PAF1_ILB = 7.43E-02tpy This value is listed in cell F54 of "PAF1_ILB" worksheet (PAF1_ILB!F54).
PAF Unit 1 Powder River Basin (PRB) subbituminous coal:
Equation (7): Hg_in_PRB_energy = Hg_in_PRB_mass*(kg/10^6 mg)/coal_heat_PAF_PRB*(1-coal_H2O_PAF_PRB/100)*(10^12 Btu/TBtu) Hg_in_PRB_energy = 4.97E+00lb/TBtu
Equation (8): Hg_contrl_effncy_PAF1_PRB = (Hg_removal_multiplier_FGDW*ln(Cl_in_coal_PRB/(1-coal_H2O_PAF_PRB/100))+Hg_removal_constant_FGDW)*100% Hg_contrl_effncy_PAF1_PRB = 5.26% EFH Boiler/FGD contrl effncy for Hg in PRB coal (negligible SCR effects on Hg control when burning subbitum coal) 10
Equation (9): Hg_emssn_factr_PAF1_PRB = Hg_in_PRB_energy*(1-Hg_contrl_effncy_PAF1_PRB/100) Hg_emssn_factr_PAF1_PRB = 4.71E+00lb/TBtu
Equation (10): Hg_emssn_PAF1_PRB = Hg_emssn_factr_PAF1_PRB*heat_input_PAF1_PRB*(ton/2000 lb) Hg_emssn_PAF1_PRB = 1.34E-03tpy This value is listed in cell PAF1_PRB!F54.
PAF Unit 1 Illinois Basin (ILB) bituminous coal fines:
Equation (11): Hg_in_ILB_fines_energy = Hg_in_ILB_fines_mass*(kg/10^6 mg)/coal_heat_PAF_ILB_fines*(1-coal_H2O_PAF_ILB_fines/100)*(10^12 Btu/TBtu) Hg_in_ILB_fines_energy = 2.52E+01lb/TBtu
Equation (12): Hg_contrl_effncy_PAF1_ILB_fines_SCR = Hg_removal_effncy_SCR_FGDW_bitum Hg_contrl_effncy_PAF1_ILB_fines_SCR = 86% Hg removal efficiency for Eastern-bitum-fired boilers w/selective-catalytic-reduction (SCR) reactor & FGD scrubber 10
Equation (13): Hg_contrl_effncy_PAF1_ILB_fines_SCR_bypass = (Hg_removal_multiplier_FGDW*ln(Cl_in_coal_ILB_fines)+Hg_removal_constant_FGDW)*100% Hg_contrl_effncy_PAF1_ILB_fines_SCR_bypass = 10.14% EFH Boiler/FGD contrl effncy for Hg in ILB coal (when flue-gas path bypasses SCR reactor) 10
Equation (14): Hg_contrl_effncy_PAF1_ILB_fines = Hg_contrl_effncy_PAF1_ILB_fines_SCR*SCR_oper_factr_PAF1+Hg_contrl_effncy_PAF1_ILB_fines_SCR_bypass*(1-SCR_oper_factr_PAF1) Hg_contrl_effncy_PAF1_ILB_fines = 41.40%
Equation (15):

Page 11 of 16calcs

Hg_emssn_factr_PAF1_ILB_fines = Hg_in_ILB_fines_energy*(1-Hg_contrl_effncy_PAF1_ILB_fines/100) Hg_emssn_factr_PAF1_ILB_fines = 1.48E+01lb/TBtu
Equation (16): Hg_emssn_PAF1_ILB_fines = Hg_emssn_factr_PAF1_ILB_fines*heat_input_PAF1_ILB_fines*(ton/2000 lb) Hg_emssn_PAF1_ILB_fines = 3.76E-03tpy This value is listed in cell F54 of "PAF1_ILB" worksheet (PAF1_ILB!F54).
PAF Unit 1 total-coal Hg emssn:
Equation (17): Hg_emssn_PAF1_coal = Hg_emssn_PAF1_ILB+Hg_emssn_PAF1_PRB+Hg_emssn_PAF1_ILB_fines Hg_emssn_PAF1_coal = 7.94E-02tpy This value is listed in cell PAF1!F54 and in air!B37.
Equation (18): Hg_in_coal_energy_PAF = (Hg_in_ILB_energy*heat_input_PAF1_ILB+Hg_in_PRB_energy*heat_input_PAF1_PRB+Hg_in_ILB_fines_energy*heat_input_PAF1_ILB_fines)/heat_input_PAF1_coal Hg_in_coal_energy_PAF = 6.26E+00lb/TBtu
Equation (19): Hg_emssn_factr_PAF1_coal = Hg_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal Hg_emssn_factr_PAF1_coal = 3.40E+00lb/TBtu
Equation (20): Hg_emssn_PAF1_coal_hrly = max_heat_input_PAF1*Hg_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) Hg_emssn_PAF1_coal_hrly = 2.36E-02lb/unit-hr This value, listed in cell PAF1!G54, is based on estimated Hg emssn factr & Title V max heat-input capacity.
Equation (21): Hg_contrl_effncy_PAF1_coal = (1-Hg_emssn_factr_PAF1_coal/Hg_in_coal_energy_PAF)*100 Hg_contrl_effncy_PAF1_coal = 45.75% PAF Unit 1 coal-region weighted-avg. boiler/SCR/FGD total-coal HCl control efficiency

**PA F Unit 1 Routine Coal-fired Organic HAP Emission Estimates:** 
Biphenyl (CAS No. 92524) coal-fired emission estimates based on EPRI's Emission Factor Handbook (EFH) are typical for organic HAP.
Biphenyl_emssn_factr_coal = 0.16lb/TBtu EFH Log-normal-mean biphenyl coal-fired emission factor 10
Equation (1): Biphenyl_emssn_PAF1_coal = Biphenyl_emssn_factr_coal*heat_input_PAF1_coal*(ton/2000lb) Biphenyl_emssn_PAF1_coal = 3.74E-03tpy = PAF Unit 1 biphenyl emission estimate, listed in PAF1!F73 and in air!B67.

**PA F Unit 1 Routine Coal-fired Radionuclide Emission Estimates:** 
Radionuclides_in_fly_ash = 53.1pCi/g of emitted PM =sum EFH geom mean factrs for Pb-210, Po-210, Ra-226, 10 Ra-228, Th-228, Th-230, Th-232, U-234, U-235, & U-238 Equation (1): Radionuclide_emssn_factr_PAF1_coal = Radionuclides_in_fly_ash*PM_fil_emssn_factr_PAF1_coal*(453.5924 g/lb) Radionuclide_emssn_factr_PAF1_coal = 2.55E+03pCi/MBtu
Equation (2): Radionuclide_emssn_PAF1_coal = Radionuclide_emssn_factr_PAF1_coal*(10^6 MBtu/TBtu)*heat_input_PAF1_coal*(1 Ci/10^12 pCi) Radionuclide_emssn_PAF1_coal = 1.19E-01Ci/yr This value is given in PAF1!F159 and is included in air!B161.
**Sample Calculations for PAF Unit 1 Alternate-Fuel (Lightoff-Oil) Criteria-Pollutant & Hazardous-Air-Pollutant (HAP) Emission Estimates**
Distillate fuel oil is fired for lightoff during unit startup (and may also be fired at other times to ensure flame stability). During the oil-fired portion of startups for PAF Unit 3, the electrostatic-precipitator (ESP) PM control system is not energized due to safety concerns. PAF Units 1-2 FGD scrubbers are in-service whenever fire is in the boiler. PAF lightoff-oil emissions were conservatively estimated using AP-42 uncontrolled emission factors (Ref. 21) for distillate fuel oil combustion.
General Input Variables: Value Units Notes Reference
lightoff_oil_burn_PAF1_2 = 60,706gal/yr CY06 PAF Units 1-2 distillate (No. 2) fuel-oil burn. 2 turbine_startups_PAF1 = 6 Number of CY06 PAF Unit 1 turbine startups 2 turbine_startups_PAF1_2 = 16 Number of CY06 PAF Units 1-2 total turbine startups 2 lightoff_oil_heat_PAF = 138,500Btu/gal CY06 PAF plant-total lightoff-oil heat content (HHV) 2 lightoff_oil_S_PAF = 0.2% weight CY06 PAF plant-total lightoff-oil sulfur content 2 PM_fil_emssn_factr_distillate_oil = 2lb/10^3 gal (kgal) Filterable particulate-matter (PM_fil) uncontrolled emissn factr for distillate-oil combustn in boilers 21 SO2_emssn_factr_distillate_oil = 142lb/(kgal-%S) Sulfur dioxide (SO2) uncontrolled emissn factr for distillate-oil combustion in boilers 21 NOx_emssn_factr_distillate_oil = 24lb/kgal Nitrogen oxides (NOx) uncontrolled emissn factr for distillate-oil combustion in boilers 21 CO_emssn_factr_distillate_oil = 5lb/kgal Carbon monoxide (CO) uncontrolled emissn factr for distillate-oil combustion in boilers 21 VOC_emssn_factr_distillate_oil = 0.2lb/kgal Volatile organic compds (VOC) uncontrolled emissn factr for distillate-oil combustion in boilers 21 SO3_emssn_factr_distillate_oil = 5.7lb/(kgal-%S) Sulfur trioxide (SO3) uncontrolled emissn factr for distillate-oil combustion in boilers 21 SO3_mol_wt = 80.0622lb/lb-mole Sulfur trioxide (SO3) molecular weight 11
Trace-Element & Organic HAP Inputs:
Pb_emssn_factr_distillate_oil = 9lb/10^12 Btu (TBtu) Lead (Pb) emissn factr for distillate-oil combustion in boilers 21 CH2O_emssn_factr_distillate_oil = 0.061lb/kgal Formaldehyde (CH2O) uncontrolled emission factr for distillate-oil combustion in boilers 21

**PA F Unit 1 Lightoff-Oil Criteria-Pollutant & Non-HAP Emission Estimates:** 
Filterable Particulate Matter (PM_fil)
Equation (1): lightoff_oil_burn_PAF1 = lightoff_oil_burn_PAF1_2*turbine_startups_PAF1/turbine_startups_PAF1_2 lightoff_oil_burn_PAF1 = 22,765gal/yr
Equation (2): PM_fil_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*PM_fil_emssn_factr_distillate_oil*(ton/2000 lb) PM_fil_emssn_PAF1_lightoff_oil = 2.28E-02tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C13.
Sulfur Dioxide (SO2)
Equation (3): SO2_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*SO2_emssn_factr_distillate_oil*lightoff_oil_S_PAF*(ton/2000 lb) SO2_emssn_PAF1_lightoff_oil = 3.23E-01tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C17.
Nitrogen Oxides (NOx)
Equation (4): NOx_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*NOx_emssn_factr_distillate_oil*(ton/2000 lb) NOx_emssn_PAF1_lightoff_oil = 2.73E-01tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C18.
Carbon Monoxide (CO)
Equation (5): CO_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*CO_emssn_factr_distillate_oil*(ton/2000 lb) CO_emssn_PAF1_lightoff_oil = 5.69E-02tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C19.
Volatile Organic Compounds (VOC)
Equation (6): VOC_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*VOC_emssn_factr_distillate_oil*(ton/2000 lb) VOC_emssn_PAF1_lightoff_oil = 2.28E-03tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C20.
Sulfuric Acid (H2SO4)
Equation (7):

Page 12 of 16calcs

H2SO4_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*SO3_emssn_factr_distillate_oil*lightoff_oil_S_PAF*H2SO4_to_SO3_molar_ratio/100*H2SO4_mol_wt/SO3_mol_wt*(ton/2000 lb) H2SO4_emssn_PAF1_lightoff_oil = 1.59E-02tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C21.

**PA F Unit 1 Lightoff-Oil Hazardous-Air-Pollutant (HAP) Emission Estimates:** 
Lead (Pb) and formaldehyde (CH2O) emission estimates based on EPA's AP-42 distillate-oil emission factors are typical for lightoff-oil trace-element and organic HAP emissions, respectively.

Pb Emission Estimates:
Equation (1): Pb_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*lightoff_oil_heat_PAF*Pb_emssn_factr_distillate_oil*(TBtu/10^12 Btu)*(ton/2000 lb) Pb_emssn_PAF1_lightoff_oil = 1.42E-05tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C35.
Formaldehyde (CH2O) Emission Estimates:
Equation (2): CH2O_emssn_PAF1_lightoff_oil = lightoff_oil_burn_PAF1*(kgal/10^3 gal)*CH2O_emssn_factr_distillate_oil*(ton/2000 lb) CH2O_emssn_PAF1_lightoff_oil = 6.94E-04tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C80.
**Sample Calculations for PAF Unit 1 Alternate-Fuel (Used-Oil) Criteria-Pollutant & Hazardous-Air-Pollutant (HAP) Emission Estimates**
General Input Variables: Value Units Notes Reference
used_oil_burn_PAF1 = 9,995gallons/yr (gal/yr) CY06 PAF Unit 1 used-oil burn 22 specific_grav = 0.9g/mL Nominal value for TVA-wide used-oil samples 23 used_oil_ash = 0.1weight % Nominal value for TVA-wide used-oil samples used_oil_S 0.4weight % Nominal value for TVA-wide used-oil samples PM_fil_emssn_factr_used_oil = 64lb/(kgal-%ash) Filterable particulate-matter (PM_fil) uncontrolled emissn factr for used-oil combustn in boilers 24 PM10_fil_emssn_factr_used_oil = 51lb/(kgal-%ash) Filterable particulate-matter (PM_fil) uncontrolled emissn factr for used-oil combustn in boilers 24 SO2_emssn_factr_used_oil = 147lb/(kgal-%S) Sulfur dioxide (SO2) uncontrolled emissn factr for used-oil combustion in boilers 24 NOx_emssn_factr_used_oil = 19lb/kgal Nitrogen oxides (NOx) uncontrolled emissn factr for used-oil combustion in boilers 24 CO_emssn_factr_used_oil = 5lb/kgal Carbon monoxide (CO) uncontrolled emissn factr for used-oil combustion in boilers 24 VOC_emssn_factr_used_oil = 1lb/kgal Volatile organic compds (VOC) uncontrolled emissn factr for used-oil combustion in boilers 24 PM_fil_emssn_factr_PAF1_coal = 0.106lb/10^6 Btu (MBtu) CY06 PAF Unit 1 coal-fired filterable particulate-matter (PM_fil) stack-test measurements (average) 4 SOx _uncontrlld_emssn_factr_bitum = 38lb/(ton as-fired coal*%S) AP-42 uncontrolled bituminous-coal SOx emssion factor (expressed as SO2) for cyclone-fired boilers 6 SOx _uncontrlld_emssn_factr_subbit = 35lb/(ton as-fired coal*%S) AP-42 uncontrolled subbituminous-coal SOx emssion factor (expressed as SO2) for cyclone-fired boilers 6 NOx_uncontrlld_emssn_factr_bitum = 33lb/(ton AR coal) AP-42 uncontrolled bituminous-coal NOx emission factor for cyclone-fired boilers 6 NOx_uncontrlld_emssn_factr_subbit = 17lb/(ton AR coal) AP-42 uncontrolled subbituminous-coal NOx emission factor for cyclone-fired boilers 6 SO2_emssn_PAF1_CEMS = 15,146tons/yr (tpy) CY06 PAF Unit 1 CEMS sulfur dioxide (SO2) emssn data (coal + alternate fuels) 7 heat_input_PAF1_CEMS = 44,104,732x 10^6 Btu/yr (MBtu/yr) CY06 PAF Unit 1 CEMS heat-input estimate (coal + alternate fuels) 7 NOx_emssn_PAF1_CEMS = 13,145tpy CY06 PAF Unit 1 CEMS nitrogen oxides (NOx) emission measurements (coal + alternate fuels) 7 CO_contrl_effncy_PAF1 = 0% PAF boilers have no add-on CO control equipment VOC_contrl_effncy_PAF1 = 0% PAF boilers have no add-on VOC control equipment
Trace-Element HAP Inputs, taking Lead (Pb) & Hydrogen Chloride (HCl) as examples:
Pb_in_used_oil_mass = 2.42mg/kg (as-fired) Mean lead (Pb) mass concentration in CY03 PAF used-oil analyses 25 Cl_in_used_oil_mass = 179mg/kg (as-fired) Mean total halogen (presume Cl) mass concentration in CY03 PAF used-oil analyses 25 HCl_emssn_factr_used_oil = 66lb/(kgal-%Cl) Hydrogen chloride (HCl) uncontrolled emissn factr for used-oil combustion in boilers 24 Pb_contrl_effncy_PAF1 = 97.26% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E41 in "PAF1" wksheet) HCl_contrl_effncy_PAF1 = 97.00% PAF Unit 1 coal-region weighted-avg. boiler/FGD total-coal HCl control efficiency (cell E52 in "PAF1" wksheet)

**PA F Unit 1 Used-Oil Criteria-Pollutant Emission Estimates:** 
Filterable Particulate Matter (PM_fil)
Equation (1): PM_fil_inputs_PAF1_used_oil = used_oil_burn_PAF1*PM_fil_emssn_factr_used_oil*(kgal/1000 gal)*used_oil_ash*(ton/2000 lb) PM_fil_inputs_PAF1_used_oil = 3.20E-02tpy
Equation (2): coal_ash_PAF1 = (coal_burn_PAF1_ILB*coal_ash_PAF_ILB+coal_burn_PAF1_PRB*coal_ash_PAF_PRB+coal_burn_PAF1_ILB_fines*coal_ash_PAF_ILB_fines)/coal_burn_PAF1 coal_ash_PAF1 = 9.01%-weight (AR basis)
Equation (3): coal_heat_PAF1 = (coal_burn_PAF1_ILB*coal_heat_PAF_ILB+coal_burn_PAF1_PRB*coal_heat_PAF_PRB+coal_burn_PAF1_ILB_fines*coal_heat_PAF_ILB_fines)/coal_burn_PAF1 coal_heat_PAF1 = 1.16E+04Btu [HHV]/lb AR basis
Equation (4): PM_fil_uncontrlld_emssn_factr_PAF1_coal = (coal_ash_PAF1/100)/coal_heat_PAF1*(ash_partition_to_flue_gas_PAF/100)*(10^6 Btu/MBtu) PM_fil_uncontrlld_emssn_factr_PAF1_coal = 1.94E+00lb/MBtu
Equation (5): PM_fil_contrl_effncy_PAF1 = (1-PM_fil_emssn_factr_PAF1_coal/PM_fil_uncontrlld_emssn_factr_PAF1_coal)*100 PM_fil_contrl_effncy_PAF1 = 94.54%
Equation (6): PM_fil_emssn_PAF1_used_oil = PM_fil_inputs_PAF1_used_oil*(1-PM_fil_contrl_effncy_PAF1/100) PM_fil_emssn_PAF1_used_oil = 1.75E-03tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$13.
Sulfur Dioxide (SO2)
Equation (7): coal_S_PAF1 = (coal_burn_PAF1_ILB*coal_S_PAF_ILB+coal_burn_PAF1_PRB*coal_S_PAF_PRB+coal_burn_PAF1_ILB_fines*coal_S_PAF_ILB_fines)/coal_burn_PAF1 coal_S_PAF1 = 2.75%-weight (AR basis)
Equation (8): SO2_uncontrlld_emssn_factr_PAF1_coal = (SOx_uncontrlld_emssn_factr_bitum*(coal_burn_PAF1_ILB*coal_S_PAF1_ILB*+coal_burn_PAF1_ILB_fines*coal_S_PAF1_ILB_fines)+ SOx_uncontrlld_emssn_factr_subbit*coal_burn_PAF1_PRB*coal_S_PAF1_PRB)/(coal_heat_PAF1*coal_burn_PAF1*2000 lb/ton)*(10^6 Btu/MBtu) SO2_uncontrlld_emssn_factr_PAF1_coal = 4.49E+00lb/MBtu
Equation (9): SO2_emssn_factr_PAF1_CEMS = SO2_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS SO2_emssn_factr_PAF1_CEMS = 6.87E-01lb/MBtu
Equation (10): SO2_contrl_effncy_PAF1 = (1-SO2_emssn_factr_PAF1_CEMS/SO2_uncontrlld_emssn_factr_PAF1_coal)*100 SO2_contrl_effncy_PAF1 = 84.71%
Equation (11): SO2_emssn_PAF1_used_oil = used_oil_burn_PAF1*SO2_emssn_factr_used_oil*(kgal/1000 gal)*used_oil_S*(1-SO2_contrl_effncy_PAF1/100)*(ton/2000 lb) SO2_emssn_PAF1_used_oil = 4.49E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$17.

Page 13 of 16calcs

Nitrogen Oxides (NOx)
Equation (12): NOx_uncontrlld_emssn_factr_PAF1_coal = (NOx_uncontrlld_emssn_factr_bitum*(coal_burn_PAF1_ILB+coal_burn_PAF1_ILB_fines)+ NOx_uncontrlld_emssn_factr_subbit*coal_burn_PAF1_PRB)/(coal_heat_PAF1*coal_burn_PAF1*2000 lb/ton)*(10^6 Btu/MBtu) NOx_uncontrlld_emssn_factr_PAF1_coal = 1.41E+00lb/MBtu
Equation (13): NOx_emssn_factr_PAF1_CEMS = NOx_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS NOx_emssn_factr_PAF1_CEMS = 5.96E-01lb/MBtu
Equation (14): NOx_contrl_effncy_PAF1 = (1-NOx_emssn_factr_PAF1_CEMS/NOx_uncontrlld_emssn_factr_PAF1_coal)*100 NOx_contrl_effncy_PAF1 = 57.72%
Equation (15): NOx_emssn_PAF1_used_oil = used_oil_burn_PAF1*NOx_emssn_factr_used_oil*(kgal/1000 gal)*(1-NOx_contrl_effncy_PAF1/100)*(ton/2000 lb) NOx_emssn_PAF1_used_oil = 4.01E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$18.
Carbon Monoxide (CO)
Equation (16): CO_emssn_PAF1_used_oil = used_oil_burn_PAF1*CO_emssn_factr_used_oil*(kgal/1000 gal)*(1-CO_contrl_effncy_PAF1/100)*(ton/2000 lb) CO_emssn_PAF1_used_oil = 2.50E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$19.
Volatile Organic Compounds (VOC)
Equation (17): VOC_emssn_PAF1_used_oil = used_oil_burn_PAF1*VOC_emssn_factr_used_oil*(kgal/1000 gal)*(1-VOC_contrl_effncy_PAF1/100)*(ton/2000 lb) VOC_emssn_PAF1_used_oil = 5.00E-03tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$20.

**PA F Unit 1 Used-Oil Trace-Element Hazardous-Air-Pollutant (HAP) Emission Estimates:** 
Lead (Pb) and Hydrogen Chloride (HCl) emission estimates based on CY03 analyses & AP-42 emission factors are typical for used-oil trace-element HAP emissions.

Pb Emission Estimates:
Equation (1): Pb_inputs_PAF1_used_oil = used_oil_burn_PAF1*specific_grav*(3785.412 mL/gal)*(lb/453.5924g)*Pb_in_used_oil_mass*(1kg/10^6mg)*(ton/2000 lb) Pb_inputs_PAF1_used_oil = 9.09E-05tpy
Equation (2): Pb_emssn_PAF1_used_oil = Pb_inputs_PAF1_used_oil*(1-Pb_contrl_effncy_PAF1/100) Pb_emssn_PAF1_used_oil = 2.49E-06tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!C35.

HCl Emission Estimates:
Equation (3): HCl_emssn_PAF1_used_oil = used_oil_burn_PAF1*HCl_emssn_factr_used_oil*(kgal/1000 gal)*Cl_in_used_oil_mass*(kg/10^6 mg)*(100%)*(1-HCl_contrl_effncy_PAF1/100)*(ton/2000 lb) HCl_emssn_PAF1_used_oil = 1.77E-04tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$30.
**Sample Calculations for PAF Unit 1 Alternate-Fuel (Tire-Derived-Fuel [TDF]) Criteria-Pollutant & Hazardous-Air-Pollutant (HAP) Emission Estimates**
General Input Variables: Value Units Notes Reference
TDF_burn_PAF = 0tons/yr (tpy) CY06 PAF plant-total as received/fired (AR) tire-derived-fuel (TDF) burn 26 TDF_heat_ALF = 16,363Btu/lb CY03 Allen Fossil Plant (ALF) TDF AR heat content 26 TDF_ash_ALF = 6.26% weight CY03 ALF TDF AR ash content 26 SOx _uncontrlld_emssn_factr_ALF_TDF = 1.86lb SO2/10^6 Btu CY03 ALF TDF sulfur-oxides (SOx) emission factor (expressed as sulfur dioxide [SO2]) 26
PM & Gaseous Trace-Element HAP Inputs:
Pb_uncontrlld_emssn_factr_TDF = 3.86E-04lb/10^6 Btu (MBtu) TDF uncontrolled lead (Pb) emission factor 27 Pb_contrl_effncy_PAF1 = 97.26% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E40 in "PAF1" wksheet)

**PA F Unit 1 TDF-fired Criteria-Pollutant Emission Estimates:** 
Filterable Particulate Matter (PM_fil)
Equation (1): TDF_burn_PAF1 = TDF_burn_PAF*coal_burn_PAF1/coal_burn_PAF TDF_burn_PAF1 = 0.00E+00tpy CY06 PAF plant-total TDF burn apportioned according to unit-specific share of plant-total coal burn.
Equation (2): PM_fil_uncontrlld_emssn_factr_PAF1_TDF = (TDF_ash_ALF/100)/TDF_heat_ALF*(ash_partition_to_flue_gas_PAF/100)*(10^6 Btu/MBtu) PM_fil_uncontrlld_emssn_factr_PAF1_TDF = 9.56E-01lb/MBtu
Equation (3): PM_fil_emssn_PAF1_TDF = TDF_burn_PAF1*(2000 lb/ton)*TDF_heat_ALF*PM_fil_uncontrlld_emssn_factr_PAF1_TDF*(MBtu/10^6 Btu)*(1-PM_fil_contrl_effncy_PAF1/100)*(ton/2000 lb) PM_fil_emssn_PAF1_TDF = 0.00E+00tpy This value is listed in Table 8 of the "alt_fuel" wksheet & is included in air!C13.
Sulfur Dioxide (SO2)
Equation (4): heat_input_PAF1_TDF = TDF_burn_PAF1*(2000 lb/ton)*TDF_heat_ALF*(MBtu/10^6 Btu) heat_input_PAF1_TDF = 0.00E+00MBtu/yr
Equation (5): SO2_emssn_PAF1_TDF = heat_input_PAF1_TDF*SOx_uncontrlld_emssn_factr_ALF_TDF*(1-SO2_contrl_effncy_PAF1/100)*(ton/2000 lb) SO2_emssn_PAF1_TDF = 0.00E+00tpy This value is listed in Table 8 of the "alt_fuel" wksheet & is included in air!C17.

**PA F Unit 1 TDF-fired Trace-Element Hazardous-Air-Pollutant (HAP) Emission Estimates:** 
Lead (Pb) emission estimates based on EPA's TDF emission factor are typical for TDF trace-element HAP emissions.

Pb Emission Estimates:
Equation (1): Pb_emssn_PAF1_TDF = heat_input_PAF1_TDF*Pb_uncontrlld_emssn_factr_TDF*(1-Pb_contrl_effncy_PAF1/100)*(ton/2000 lb) Pb_emssn_PAF1_TDF = 0.00E+00tpy This value is listed in Table 8 of the "alt_fuel" wksheet & is included in air!C35.
**Sample Calculations for PAF Unit 1 Alternate-Fuel (Wood-Residue) Criteria-Pollutant & Hazardous-Air-Pollutant (HAP) Emission Estimates**
General Input Variables: Value Units Notes Reference
WW_burn_PAF = 0tons/yr (tpy) CY06 PAF plant-total woodwaste (WW)burn 26 WW_H2O_COF = 45.66% CY03 Colbert Fossil Plant (COF) WWmoisture content 26 WW_ash_COF = 5.66% (as-received) CY03 COF WWas-received (AR) ash content 26 WW_S_COF = 0.06% (as-received) CY03 COF WWAR sulfur content 26 WW_heat_COF = 4,372Btu/lb (as-received) CY03 COF WWAR heat content 26 PM_fil_emssn_factr_WW_FGD = 6.60E-02lb/10^6 Btu (lb/MBtu) Filterable particulate-matter (PM_fil) emission factor for WW-fired boilers with FGD scrubber PM controls 28 AP42_SO2_emssn_factr_WW= 2.50E-02lb/MBtu Sulfur dioxide (SO2) emission factor for WW-fired boilers with no or PM-only air-pollutn controls 28 NOx_uncontrlld_emssn_factr_WW= 2.20E-01lb/MBtu Nitrogen oxides (NOx) emission factor for WW-fired boilers with no or PM-only air-pollutn controls 28 CO_uncontrlld_emssn_factr_WW= 6.00E-01lb/MBtu Carbon monoxide (CO) emission factor for WW-fired boilers with no or PM-only air-pollutn controls 28 VOC_uncontrlld_emssn_factr_WW= 1.70E-02lb/MBtu Volatile organic compds (VOC) emission factor for WW-fired boilers with no or PM-only controls 28

Page 14 of 16calcs

Trace-Element & Organic HAP Inputs:
Pb_emssn_factr_WW= 4.80E-05lb/MBtu Lead (Pb) emission factor for WW-fired boilers with no or PM-only air-pollutn controls 28 CH2O_emssn_factr_WW= 4.40E-03lb/MBtu Formaldehyde (CH2O) emission factor for WW-fired boilers with no or PM-only air-pollutn controls 28

**PA F Unit 1 WW Criteria-Pollutant Emission Estimates:** 
Filterable Particulate Matter (PM_fil)
Equation (1): WW_burn_PAF1 = WW_burn_PAF*coal_burn_PAF1_opstat/coal_burn_PAF WW_burn_PAF1 = 0.00E+00tpy CY06 PAF plant-total WWburn apportioned according to unit-specific share of plant-total coal burn.
Equation (2): PM_fil_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*PM_fil_emssn_factr_WW_FGD*(ton/2000 lb) PM_fil_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C13.
Sulfur Dioxide (SO2)
Equation (3): SO2_uncontrlld_emssn_factr_WW= WW_S_COF/100/WW_heat_COF*(10^6 Btu/MBtu)*SO2_mol_wt/S_mol_wt SO2_uncontrlld_emssn_factr_WW= 2.52E-01lb/MBtu
Equation (4): SO2_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*SO2_uncontrlld_emssn_factr_WW*(1-SO2_contrl_effncy_PAF1/100)*(ton/2000 lb) SO2_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C17.
Nitrogen Oxides (NOx)
Equation (5): NOx_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*NOx_uncontrlld_emssn_factr_WW*(1-NOx _contrl_effncy_PAF1/100)*(ton/2000 lb) NOx_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C18.
Carbon Monoxide (CO)
Equation (8): CO_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*CO_uncontrlld_emssn_factr_WW*(1-CO_contrl_effncy_PAF1/100)*(ton/2000 lb) CO_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C19.
Volatile Organic Compounds (VOC)
Equation (9): VOC_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*VOC_uncontrlld_emssn_factr_WW*(1-VOC_contrl_effncy_PAF1/100)*(ton/2000 lb) VOC_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C20.

**PA F Unit 1 WW Hazardous-Air-Pollutant (HAP) Emission Estimates:** 
Lead (Pb) Emission Estimates:
Equation (1): Pb_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*Pb_emssn_factr_WW*(ton/2000 lb) Pb_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C35.

CH2O Emission Estimates:
Equation (2): CH2O_emssn_PAF1_WW= WW_burn_PAF1*(2000 lb/ton)*WW_heat_COF*(MBtu/10^6 Btu)*CH2O_emssn_factr_WW*(ton/2000 lb) CH2O_emssn_PAF1_WW= 0.00E+00tpy This value is listed in Table 13 of the "alt_fuel" wksheet & is included in air!C80.
**Sample Calculations for PAF Unit 1 Alternate-Fuel (Used-Boiler-Cleaning Chemicals [EDTA]) Hazardous-Air-Pollutant (HAP) Emission Estimates**
General Input Variables: Value Units Notes Reference
used_EDTA_burn_volume_PAF1 = 0gallons/yr CY06 PAF Unit 1 ethylenediamine-tetraacetic-acid (EDTA) used-boiler-cleaning-chemicals total burn volume 29 No_of_rinses = 4 No. of rinses included in all CY03 TVA composite EDTA used-blr-cleaning-chemical solutions burned/evaporated 30 EDTA_burn_fraction_PAF1 = 1 Assumed composite solution for any PAF unit EDTA cleaning would be burned in PAF Unit 1 alone
Trace-Element Inputs, taking lead (Pb) as an example:
Pb_in_EDTA_composite = 2.0milligrams per liter (mg/L) TCLP Extract analysis of worst-case composite EDTA solution from CY02 COF Unit 1 boiler cleaning 31 Pb_contrl_effncy_PAF1 = 97.26% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E41 in "PAF1" wksheet)
Lead (Pb) Emission Estimates:
Equation (1): Pb_inputs_PAF1_EDTA = EDTA_drain_volume_PAF1*(1+No_of_rinses)*EDTA_burn_fraction_PAF1*(3.785412 L/gal)*(lb/453592.4 mg)*Pb_in_EDTA_composite*(ton/2000 lb) Pb_inputs_PAF1_EDTA = 0.00E+00tons/yr (tpy)
Equation (2): Pb_emssn_PAF1_EDTA = Pb_inputs_PAF1_EDTA*(1-Pb_contrl_effncy_PAF1/100) Pb_emssn_PAF1_EDTA = 0.00E+00tpy This value is listed in Table 14 of the "alt_fuel" wksheet & is included in air!C35.
**Sample Calculations for PAF Fugitive-Dust Emission Estimates**
Potential emission estimates for coal-, limestone-, & byproduct-handling in the PAF Title V permit application (Ref. 32) were adapted to CY06 process quantities (Ref. 33) to estimate CY06 fugitive-dust emissions. See Ref. 32 for sample calculations.

**References:**
(1) Excel file "CY 2006 TRI Coal Data.xls" in 2-13-07 e-mail from T.V. Masterson to C.M. Anderson et al., posted in CY 06\Release Estimates\Coal and Limestone folder on FPG Env Affr - TRI ("chapgfs5") server.
(2) Excel file "CY06 Operating Statistics from DataFuser (20070122).xls" in CY 06\Release Estimates\Operating Statistics folder on FPG Env Affr - TRI ("chapgfs5") server.
(3) Excel file "Current Particulate Test Reports Updated 1-23-07.xls" in CY06\Release Estimates\Air Stack Tests folder on FPG Env Affr - TRI ("chapgfs5") server.
(4) Excel file "TRI Report CY06.xls" in 2-15-07 e-mail from K.N. Copeland to M.F. Broder et al.
(5) US EPA,Compilation of Air Pollutant Emission Factors(AP-42), Vol. I, 5th Edition, Supplement E, Section 1.1, Bituminous & Subbituminous Coal Combustion, 9-98.
(6) Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-8-07 e-mail from W.M. Sisk to J.D. Lokey.
(7) Median trace-element coal concentrations listed in the Electric Power Research Institute (EPRI) LARK-TRIPP (LT) Emission Estimation Model, RY2006 v1, Beta 1 (2-12-07); LT compilation was derived from EPRI's PISCES Database (February 2003 & 2005 updates), except mercury and chlorine (EPA ICR Part II coal database, May 2000).
(8) PAF coal-fines trace-element data derived from Excel file "Fine Refuse Metals R1 1-11-06.xls" in 1-11-06 e-mail from W.A. Thomas to M.F. Broder et al.
(9) Chloride (Cl) concentrations for PAF Illinois Basin & PRB coals reflect TVA's CY99 Information Collection Request (ICR) analyses (final compilation in 3-16-00 e-mail from J.D. Eady to R.W. Burbage).
(10) Electric Power Research Institute (EPRI),Emission Factors Handbook [EFH]--Guidelines for Estimating Trace Substance Emissions from Fossil Fuel Steam Electric Plants, Report No. EPRI TR-105611, November 1995, as updated in 9-98 & 2-01 EFH Addenda, 4-02 EFH Revision, & 4-05 EFH Update.
(11)Chemical Engineers' Handbook, 5th Edition, R.H. Perry & C.H. Chilton, Editors, McGraw-Hill Book Company, New York, NY, 1973.
(12) R. Hardman, R. Stacy, & E. Dismukes, "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power Plants," paper presented at US DOE-FETC Conference on Formation, Distribution, Impact and Fate of Sulfur Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, March 1998; revised by K. Harrison, 7-98; by K. Harrison & L. Monroe, 9-98 (renamed "Estimating Total Sulfuric Acid Emissions from Coal- Fired Power Plants"); by L.S. Monroe, 5-01, and by L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"), and by

Page 15 of 16calcs

K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"), and by the Electric Power Research Institute (EPRI), Publication No. 1014773, External Review Draft 2-5-07.
(13) Per 1-25-07 e-mail from R.L. Beasley to K.J. Dukes et al., archived in CY 06\Completed Questionnaire\PAF folder on FPG Env Affr - TRI ("chapgfs5") server.
(14) Per 3-19-03 e-mail from R.A. Babb to S.S. Koss et al., confirmed in 2-15-05 e-mail from J.D. Giles to C.M. Anderson.
(15) Per 1-11-01 conversation with R.A. Babb regarding vendor-guaranteed maximum SCR-exit NH3 slip at 20,000 hours SCR operation.
(16) Word file "PAF U2 Opacity Reduction Testing Final Report1.doc," 4-8-05, authored by M.A. Thompson, downloaded 5-25-05 from TVA Fossil Power Group (FPG) Air, Gas, Water, & Yard (AGWY) Systems' SO3 Mitigation website (TVA Intranet).
(17) S.L. Wilson, K.E. Harrison, & L.S. Monroe, "A Method for Estimating Total Ammonia Emissions from Stationary Power Plants," 10-05.
(18) Anhydrous & aqua ammonia receipts/usage listed in 1-25-07 e-mail from R.L. Beasley to K.J. Dukes et al., archived in CY 06\Completed Questionnaire\PAF folder on FPG Env Affr - TRI ("chapgfs5") server.
(19) NH3 unloading fugitive emission factor, derived from pipe/hose dimensions at TVA's Paradise Fossil Plant (see Table 11 in "NH3" worksheet)
(20) TVA assumption for Rocky Mtn bituminous (RMB) coal penetration & environmental factors based on PRB factors from Ref. 17, based on similar alkaline contents for these Western coals.
(21) US EPA,Compilation of Air Pollutant Emission Factors(AP-42), Vol. I, 5th Edition, Supplement E, Section 1.3, Fuel Oil Combustion, 9-98.
(22) Excel file "PAFoilburnedrptbegin2006.xls" in 2-7-07 e-mail from K.J. Dukes to J.D. Lokey.
(23) Per 3-26-98 phone communication between D.M. Varnell & J.D. Lokey.
(24) US EPA,Compilation of Air Pollutant Emission Factors(AP-42), Vol. I, 5th Edition, Supplement B, Section 1.11, Waste Oil Combustion, 10-96
(25) Excel file "USEDOIL_FPG Reported in CY 03.xls" in 3-4-04 e-mail from M.F. Broder to J.D. Lokey et al.
(26) Excel file "CY2006 Alternative Fuels TRI Data.xls," in CY 06\Release Estimates\Alternate Fuels folder on FPG Env Affr - TRI ("chapgfs5") server.
(27) US EPA,Air Emissions from Scrap Tire Combustion, EPA-600/R-97-115, October 1997.
(28) US EPA,Compilation of Air Pollutant Emission Factors(AP-42), Vol. I, 5th Edition, Supplement G, Section 1.6, Wood Residue Combustion in Boilers, 3-02 [Update 2003, revised 9-03].
(29) Word file "2006 Chemicals used for Fossil Boiler Cleanings.doc" in CY 06\Release Estimates\EDTA Boiler Cleaning folder on FPG Env Affr - TRI ("chapgfs5") server.
(30) Per 4-5-04 email from H.G. Evans to S.S. Koss et al., all composite EDTA used-boiler-cleaning-chemical solutions burned/evaporated in CY03 consisted of first-flush EDTA drain + 4 rinses.
(31) Per 3-13-03 e-mail fr. S.S. Koss to R.W. Burbage, TCLP Extract analyses of composite (drain + rinses) EDTA solutn fr. 11-11-02 Colbert Fossil Plt (COF) Unit 1 blr cleaning were deemed "worst-case" for all TVA blr cleanings.
(32) PAF Title V permit application submitted to KY Division for Air Quality, 12-3-96.
(33) Excel file "CY2006 Coal and Limestone Handled.xls" in 2-5-07 e-mail from S.L. Priddy to J.D. Lokey & M.F. Broder
(34) US EPA, Draft "Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon", Jan. 2002, as cited in "Particulate Speciation Profiles for Selected Source Types" posted 3-16-06 on VISTAS website providing CALPUFF modeling information for BART applications (http://vistas-sesarm.org/BART/calpuff.asp) & in National Park Service (NPS) website (http://www2.nature.nps.gov/air/permits/ect/ectCoalFiredBoiler.cfm)
(35) Excel file "2006FinalCycloneFurnaceESPpmSpeciationProfile.xls" posted on National Park Service (NPS) website (http://www2.nature.nps.gov/air/permits/ect/ectCoalFiredBoiler.cfm).
(36) Excel file "PAF fines burn CY06.xls" in CY 06\Release Estimates\PAF Coal Wash folder on FPG Env Affr - TRI ("chapgfs5") server. TVA Environmental Technologies 03/26/07

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