# opstat

CY05 Paradise Fossil Plant (PAF) Plant Operating Statistics Report*

Parameter Unit 01 Unit 02 Unit 03 Unit 1_2 Unit 3_3 Unit 1_3 Average Hourly Gross Load (MW) 646 640 840 643 840 695 Gross Generation (MWh) 4,776,620 5,410,408 4,794,528 10,187,028 4,794,528 14,981,556 Total Station Use (MWh) 367,536 349,920 290,056 717,456 290,056 1,007,512 Net Generation (MWh) 4,409,084 5,060,488 4,504,472 9,469,572 4,504,472 13,974,044 Total Station Use Percent (percent) 7.69 6.47 6.05 7.04 6.05 6.73 Capacity Factor (percent) 77.5 87.7 47.6 82.6 47.6 66.9 Hours of Use (hours) 7397 8452 5,705 15848 5705 21,553 Number of Turbine Startups (No.) 12 4 13 16 13 29 Number of Cold Startups (No.) 6 4 10 10 10 20 Gross Heat Rate (Btu/kWh) 8976 9062 9,872 9024 9,877 9297 Net Heat Rate with Oil (Btu/kWh) 9,724 9,689 10,507 9,708 10,513 9,967 Net Heat Rate without Oil (Btu/kWh) 9,724 9,689 10,507 9,705 10,507 9,964 Boiler Efficiency (percent) 88.7 89.1 85.9 88.9 85.9 Moisture in Fuel Boiler Loss (percent) 1.19 1.25 3.21 1.22 3.21 Hydrogen Loss (percent) 3.87 3.83 4.15 3.85 4.15 Dry Gas Loss (percent) 5.83 5.37 5.36 5.59 5.36 Combustibles in Fly Ash Loss (percent) 0.038 0.057 0.102 0.048 0.102 Fixed Losses (percent) 0.4 0.4 1.3 0.4 1.3 Total Boiler Losses (percent) 11.3 10.9 14.1 11.1 14.1 Throttle Pressure (psig) 2392 2397 3475 2395 3475 Throttle Temperature (deg F) 1050 1050 988.8 1050 988.8 Reheat Temperature (deg F) 990.3 985.5 965.2 987.7 965.2 Condenser Back Pressure (in. Hg) 2.16 2.50 2.75 2.34 2.75 CCWInlet Temperature (deg F) 67.2 69.3 80.8 68.3 80.8 Air Preheater Air Entering Temp (deg F) 157.4 161.7 110.6 159.7 110.6 Exit Gas Temperature (deg F) 295.9 299.0 307.7 297.6 307.7 Dry Gas Loss Temperature (deg F) 78.7 78.7 97.5 78.7 97.5 Throttle/Feedwater flow (Klb) 33,658,70938,644,519 ######## 72,303,228 ######## 109,153,019 Superheat Attemperation (percent) 0.022 0.012 0 0.017 0 0.011 Reheat Attemperation (percent) 0.086 0.091 0.801 0.088 0.801 0.329 Makeup Water % (percent) 0.927 1.233 1.21 1.091 1.21 1.131 Building Heating Steam % (percent) 0.000 0.001 0 0.031 0 0.021 Total Air (percent) 122.0 121.2 121.6 121.5 121.6 Total Air at Air Heater Outlet (percent) 143.0 131.2 126.8 136.6 126.8 Coal Burn (Klb) 3,732,920 4,255,235 5,138,936 7,988,155 5,138,936 13,127,091 Combustibles in Fly Ash (percent) 1.72 2.58 4.53 2.20 4.53 3.11 Moisture in Coal, As Fired (percent) 11.9 12.5 25.5 12.2 25.5 17.4 Volatile Matter in Coal, As Received (percent) 34.2 34.4 31.4 34.3 31.4 33.2 Fixed Carbon in Coal, As Received (percent) 45.4 44.5 36.3 44.9 36.3 41.6 Ash Content of Coal, As Received (percent) 8.54 8.57 6.83 8.56 6.83 7.88 Coal Heating Value, As Received (Btu/lb) 11,486 11,522 9,210 11,505 9,210 10,607 Sulfur in Coal, As Received (percent) 2.69 2.69 1.06 2.69 1.06 2.05 Oil Fired (gal.) 134,967 44,989 178,967 179,956 178,967 358,923 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 PRB Coal Burn, tons/yr** 18,585 29,139 1,834,221 47,724 1,834,221 1,881,945 IL Basin Coal Burn, tons/yr** 1,847,875 2,091,644 734,726 3,939,519 734,726 4,674,245 Total Coal Burn, tons/yr 1,866,460 2,120,783 2,568,947 3,987,243 2,568,947 6,556,190 Percent difference, (1-coalstats/opstats)*100 0.00 0.32 0.02 0.17 0.02 0.11 *Reference: DataFuser output 01/23/06 (Plant 12MTD Operating Statistics Report at PAF for December 2005) (Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in FPG Env Affr - TRI folder on "Chapgfs5" server) **Reference: Coal Clerk data in Excel file "CoalStats2005.xls" in 1-19-06 e-mail from M.A. Pendley to J.D. Lokey. 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. TVA Environmental Technologies 7/12/2006 Page 1 of 1

# CEMS



# CY 2005 CONTINUOUS EMISSION MONITORING SYSTEM (CEMS) DATA* **Paradise Fossil Plant (PA F)** 


# UNIT/ **STACK SO2**  **NOx Heat Input**  **CY05 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 13,563 0.628 11,466 0.531 43,191,735 42,875,391 1.007 PAF 2 17,320 0.651 14,125 0.531 53,241,517 49,030,801 1.086 PAF 3 53,519 2.31 10,289 0.444 46,316,269 47,329,486 0.979 PAF TOTAL 84,402 1.18 35,879 0.503 142,749,521 139,235,679 1.025

*Reference: Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey.

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 13.563 0.628 11.466 0.531 43.191735 PAF2 17.320 0.651 14.125 0.531 53.241517 PAF3 53.519 2.311 10.289 0.444 46.316269

Data captured (as values) from reference:



# NOx **Heat Input** tons/yr 10^12 Btu/yr OS HI, % of CY05 PAF1 794 18.384697 42.57 PAF2 972 22.270212 41.83 PAF3 1127 26.095902 56.34

TVA Environmental Technologies 07/12/06 **AN NUA** **L**

**OZONE SEA SON (OS)** 

Page 1 of 1

## coal_qual **CY05 PARADISE FOSSIL PLANT (PAF) COAL BURN QUANTITIES & ANALYSES***
**PAF UNITS 1-2 COAL ANALYSIS**  **SOURCE STATE**  **TONS BURNED W. KY**  **PRB** W.KY (Illinois Basin) coals KY 3,946,354 T.Moist% = 12.2T.Moist% = 27.5 PRB Wyoming 47,724 Ash% = 8.6Ash% = 5.3 **3,994,078** Sul.% = 2.69Sul.% = 0.35 Carb% = Carb% = Hydr% = Hydr% = Nitr% = Nitr% = Oxy% = Oxy% =
BTU/lb = 11,500BTU/lb = 8,775 Cl ppm = 602Cl ppm = 50 Hg ppm = 0.1076Hg ppm = 0.105

**PAF UNIT 3 SOURCE**  **STATE TONS BURNED**  **COAL ANALYSIS** W.KY (Illinois Basin) coals KY 745,146 **W. KY PRB**  PRB Wyoming 1,824,322 T.Moist% = 12.2T.Moist% = 27.5 **2,569,468** Ash% = 8.6Ash% = 5.3 Sul.% = 2.69Sul.% = 0.35 Carb% = Carb% = Hydr% = Hydr% = Nitr% = Nitr% = Oxy% = Oxy% =
BTU/lb = 11,500BTU/lb = 8,775 Cl ppm = 602Cl ppm = 50 Hg ppm = 0.1076Hg ppm = 0.105 *Reference: Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. (CY05 coal burn, moisture, ash, sulfur, & heat contents). Note that 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).
**PAF UNITS 1-2 CY05 Usage**  % Wt input Source tons/yr As-fired Dry basis Western Bituminous (WB) 0 0% 0% Eastern (App.) Bituminous (AB) 0 0% 0% PRB Subbituminous (PRB) 47,724 1.2% 1.0% Illinois Basin Bituminous (ILB) 3,946,354 98.8% 99.0% Total Burn = 3,994,078 100.0% 100.0% **Analysis, % CY05 Usage**  **Parameter (Wtd Avg)**  Source % Ht input Moisture 12.38 WB 0% Ash 8.56 AB 0% Sulfur 2.66 PRB 0.9% ILB 99.1% Total 100.0%

Heat value 11,467Btu/lb

**PAF UNIT 3 CY05 Usage**  % Wt input Source tons/yr As-fired Dry basis Western Bituminous (WB) 0 0% 0% Eastern (App.) Bituminous (AB) 0 0% 0% PRB Subbituminous (PRB) 1,824,322 71.0% 66.9% Illinois Basin Bituminous (ILB) 745,146 29.0% 33.1% Total Burn = 2,569,468 100% 100% **Analysis, % CY05 Usage**  **Parameter (Wtd Avg)**  Source % Ht input Moisture 23.06 WB 0% Ash 6.26 AB 0% Sulfur 1.03 PRB 65.1% ILB 34.9% Total 100.0% TVA Environmental Technologies Heat value 9,565Btu/lb 07/12/06

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)
12/14/05 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)
12/15/05 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)
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 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. TVA Environmental Technologies 07/12/06

Page 3 of 3

# alt_fuel

**CY05 PAF ALTERNATE-FUEL DATA**

Units Reference: Wood waste burned, 10^3 tons/yr = 0 No CY05 WWburn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Pet coke burned, 10^3 tons/yr = 0 Not burned at TVA in CY05. Tire-derived fuel, 10^3 tons/yr = 0 No CY05 TDF burn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Limestone flux in boiler, 10^3 tons/yr = 0 PAF1-3 Not added to PAF boilers in CY05 (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Used oil burned, gal/yr = 32,685 PAF1-3 Excel file "PAFAtt1 Oper StatsReport CY 2005.xls" in 2-10-06 e-mail from M.A. Pendley to J.D. Lokey. Lightoff oil burned, gal/yr = 358,923 PAF 1-3 Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in CY 05\Release Estimates\Operating Stats folder on FPG Env Affr - TRI ("Chapgfs5") server Used boiler cleaning chemicals burned, gal/yr = 0 PAF1-3 Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - TRI 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 oil 19448 < 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 tank 19733 < 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.; CY05 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) CY05 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY05 PAF used-oil burn quantities.
**Table 4. PAF CY05 Used-Oil Air Emission Estimates**

Plant Total Uncontrolled Emissn, Controlled Emissions, ton/yr Trace Element ton/yr PAF1 PAF2 Cd 2.89E-05 7.57E-07 0.00E+00

Page 2

# alt_fuel

Cr 8.79E-05 5.54E-07 0.00E+00 Co 3.43E-06 2.05E-08 0.00E+00 Pb 2.97E-04 3.03E-06 0.00E+00 Mn 1.11E-03 5.95E-06 0.00E+00 Ni 1.80E-04 9.65E-07 0.00E+00 HCl 1.93E-02 2.90E-04 0.00E+00
Criteria/Non-HAP Pollutants Filterable particulate matter (PM_fil) 1.05E-01 2.00E-03 0.00E+00 PM < 10-micrometers (PM10_fil) 8.33E-02 8.32E-03 0.00E+00 Sulfur dioxide (SO2) 9.61E-01 6.83E-02 0.00E+00 Nitrogen oxides (NOx) 3.11E-01 5.76E-02 0.00E+00 Carbon monoxide (CO) 8.17E-02 4.08E-02 0.00E+00 Volatile organic compds (VOC) 1.63E-02 8.17E-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, CY05 used-oil emissions were estimated using CY03 PAF used-oil analyses & CY05 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.

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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 CY05 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 CY05 (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). **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

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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 CY05 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

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# 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 CY05 Lightoff-Oil Usage/Analyses** PAF1-3 PAF1 PAF2 PAF3 Total Usage, gallons/yr 134,967 44,989 178,967 358,923 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 CY05 Lightoff-Oil Air Emission Estimates, tons/yr** PAF1-3 Trace Element PAF1 PAF2 PAF3 Total Sb 2.06E-04 6.85E-05 2.73E-04 5.47E-04 As 3.74E-05 1.25E-05 4.96E-05 9.94E-05 Ba 1.87E-04 6.23E-05 2.48E-04 4.97E-04 Be 2.80E-05 9.35E-06 3.72E-05 7.46E-05 Cd 2.80E-05 9.35E-06 3.72E-05 7.46E-05 Cr 2.80E-05 9.35E-06 3.72E-05 7.46E-05 Co 8.51E-05 2.84E-05 1.13E-04 2.26E-04 Cu 5.61E-05 1.87E-05 7.44E-05 1.49E-04 Pb 8.41E-05 2.80E-05 1.12E-04 2.24E-04 Mn 5.61E-05 1.87E-05 7.44E-05 1.49E-04 Hg 2.80E-05 9.35E-06 3.72E-05 7.46E-05 Mo 7.85E-05 2.62E-05 1.04E-04 2.09E-04 Ni 2.80E-05 9.35E-06 3.72E-05 7.46E-05 Se 1.40E-04 4.67E-05 1.86E-04 3.73E-04 V 4.11E-05 1.37E-05 5.45E-05 1.09E-04 Zn 3.74E-05 1.25E-05 4.96E-05 9.94E-05 Organic HAP (CAS Number) Formaldehyde (50000) 4.12E-03 1.37E-03 5.46E-03 1.09E-02 Polycyclic organic matter (POM) 2.23E-04 7.42E-05 2.95E-04 5.92E-04

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# alt_fuel

Criteria/Non-HAP Pollutants PM_fil 1.35E-01 4.50E-02 1.79E-01 3.59E-01 PM10_fil 6.75E-02 2.25E-02 8.95E-02 1.79E-01 PM2.5_fil 1.69E-02 5.62E-03 2.24E-02 4.49E-02 PM_cond 8.77E-02 2.92E-02 1.16E-01 2.33E-01 SO2 1.92E+00 6.39E-01 2.54E+00 5.10E+00 NOx 1.62E+00 5.40E-01 2.15E+00 4.31E+00 CO 3.37E-01 1.12E-01 4.47E-01 8.97E-01 VOC 1.35E-02 4.50E-03 1.79E-02 3.59E-02 H2SO4 9.42E-02 3.14E-02 1.25E-01 2.51E-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

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# 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 CY05 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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# alt_fuel

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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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. CY05 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** * 97.83 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 99.22 0.00E+00 Boron (B) 

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

# 0.11 0.00E+00 94.77 0.00E+00 Calcium(Ca) 

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

# 2.7 0.00E+00 98.74 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 98.81 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 99.14 0.00E+00 Iron(Fe) 

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

# 2.0 0.00E+00 97.96 0.00E+00 Magnesium(Mg) 

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

# 14.0 0.00E+00 98.93 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 97.89 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 98.93 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*** 88.02 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 99.05 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.55 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 *No PAF EDTA used-boiler-cleaning chemicals were burned in CY05, per Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - 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 CY05 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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**CY05 PAF ALTERNATE-FUEL DATA**

No CY05 WWburn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.).
Not burned at TVA in CY05. No CY05 TDF burn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Not added to PAF boilers in CY05 (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Excel file "PAFAtt1 Oper StatsReport CY 2005.xls" in 2-10-06 e-mail from M.A. Pendley to J.D. Lokey. Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in CY 05\Release Estimates\Operating Stats folder on FPG Env Affr - TRI ("Chapgfs5") server

Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - TRI 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.; CY05 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) CY05 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY05 PAF used-oil burn quantities.
**Table 4. PAF CY05 Used-Oil Air Emission Estimates**

PAF1-3 % of PAF3 PAF3 Total Total Emissns 7.40E-07 1.50E-06 0.0031

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4.84E-07 1.04E-06 0.0003 1.53E-08 3.58E-08 0.00004 2.03E-06 5.06E-06 0.0011 4.80E-06 1.08E-05 0.0015 9.81E-07 1.95E-06 0.0006 8.35E-03 8.64E-03 0.0017

1.13E-03 3.12E-03 0.0001 4.69E-03 1.30E-02 0.0008 4.81E-01 5.49E-01 0.0009 6.10E-02 1.19E-01 0.0006 4.09E-02 8.17E-02 0.0064 8.18E-03 1.63E-02 0.0058 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, CY05 used-oil emissions were estimated using CY03 PAF used-oil analyses & CY05 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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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 CY05 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 CY05 (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). **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 CY05 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 0.82 0.010 0.03 0.07 0.07 0.009 0.12 0.03 0.018 0.011 0.04 0.04 0.008 0.04 0.007 0.003

6.88 0.78

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0.009 0.007 0.003 0.020 0.014 0.014 0.07 0.013 0.010 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 fired lb/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 CY05 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. CY05 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** * 97.90 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 99.22 0.00E+00 Boron (B) 

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

# 0.11 0.00E+00 94.86 0.00E+00 Calcium(Ca) 

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

# 2.7 0.00E+00 98.76 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 98.83 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 99.15 0.00E+00 Iron(Fe) 

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

# 2.0 0.00E+00 98.01 0.00E+00 Magnesium(Mg) 

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

# 14.0 0.00E+00 98.95 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 97.93 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 98.94 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*** 88.05 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 99.07 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.57 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 *No PAF EDTA used-boiler-cleaning chemicals were burned in CY05, per Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - 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 CY05 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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No CY05 WWburn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.).

No CY05 TDF burn in PAF boilers (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.). Not added to PAF boilers in CY05 (Excel file "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al.).

Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in CY 05\Release Estimates\Operating Stats folder on FPG Env Affr - TRI ("Chapgfs5") server

Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - TRI 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) CY05 PAF used-oil emissions were estimated using AP-42 emission factors, CY03 PAF used-oil analyses (for Cd, Cr, Pb, and HCl), & CY05 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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*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** * 98.67 0.00E+00 Barium(Ba) 

# 0.61 0.00E+00 99.42 0.00E+00 Boron (B) 

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

# 0.11 0.00E+00 94.89 0.00E+00 Calcium(Ca) 

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

# 2.7 0.00E+00 98.90 0.00E+00 Cobalt(Co) 

# 0.4 0.00E+00 99.11 0.00E+00 Copper(Cu) 

# 41.8 0.00E+00 99.33 0.00E+00 Iron(Fe) 

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

# 2.0 0.00E+00 98.63 0.00E+00 Magnesium(Mg) 

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

# 14.0 0.00E+00 99.14 0.00E+00 Molybdenum(Mo) 

# 0.6 0.00E+00 98.22 0.00E+00 Nickel(Ni) 

# 2.8 0.00E+00 98.91 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*** 69.34 0.00E+00 Silicon(Si) 

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

# 0.28 0.00E+00 97.64 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 99.37 0.00E+00 Zinc(Zn) 

# 30.8 0.00E+00 98.45 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 *No PAF EDTA used-boiler-cleaning chemicals were burned in CY05, per Word file "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\Boiler Cleaning folder on FPG EnvAffr - 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 0.071 ILB COAL HEAT INPUT (10^12 BTU/YR) = 42.50 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.628 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 12.20 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL ASH (AS-FIRED) % WT (AVG) 8.60 CY05 FUEL & CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,500 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.69 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 1,847,875 0.11 1.2 NA AVG OF CY01-CY05 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 = 18.69 MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS SCR operation factor (total) = 0.485 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 1.87E+06 7.12E+04 96.19 1514 496 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.43E+05 4.84E+04 80.07 1029 337 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.03E+05 2.56E+04 75.06 545 178 NA NA Condensable PM (PM_cond) NA 2.00E+04 425 139 NA NA Sulfur dioxide (SO2) NA 4.44E+06 6.28E+05 85.87 13545 4371 36577 8351 Nitrogen oxides (NOx) NA 1.43E+06 5.31E+05 63.00 11405 3695 NA NA Carbon monoxide (CO) NA 2.17E+04 2.17E+04 0.00 462 151 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 4.78E+03 4.78E+03 0.00 102 33.3 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.33E+05 4.65E+04 65.18 988 323 3,068,600 -55.3 Ammonia (NH3)(6) NA 4.34E+02 4.34E-03 99.999 9.23E-05 3.02E-05

PM Trace-Element HAP Antimony (Sb) 2.00E+00 1.53E+02 1.16E+00 99.24 2.48E-02 8.11E-03 Arsenic (As) 1.10E+01 8.40E+02 1.82E+01 97.84 3.86E-01 1.26E-01 Beryllium (Be) 2.00E+00 1.53E+02 1.81E+00 98.81 3.85E-02 1.26E-02 Cadmium (Cd) 5.00E-01 3.82E+01 1.99E+00 94.79 4.23E-02 1.38E-02 Chromium (Cr) 1.60E+01 1.22E+03 1.54E+01 98.74 3.26E-01 1.07E-01 Cobalt (Co) 3.70E+00 2.82E+02 3.37E+00 98.81 7.15E-02 2.34E-02 Lead (Pb) 1.40E+01 1.07E+03 2.18E+01 97.96 4.63E-01 1.51E-01 Manganese (Mn) 2.90E+01 2.21E+03 2.37E+01 98.93 5.03E-01 1.65E-01 Nickel (Ni) 1.90E+01 1.45E+03 1.55E+01 98.93 3.30E-01 1.08E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.86E+02 5.38E+04 1.62E+03 97.00 3.43E+01 1.12E+01 68,609 0.05 Hydrogen fluoride (HF) 9.20E+01 7.40E+03 4.44E+02 94.00 9.43E+00 3.09E+00 18,861 0.005 Mercury (Hg) 8.00E-02 6.11E+00 2.97E+00 51.32 6.32E-02 2.07E-02 126 -0.005 Selenium (Se) 1.70E+00 1.30E+02 1.56E+01 88.00 3.31E-01 1.08E-01 662 0.0005

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 1.89E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 5.53E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.19E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.53E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.34E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 6.59E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.25E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 1.93E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 4.89E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.34E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 6.80E-02 2.23E-02 136 0.003 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.55E-02 8.35E-03 51.0 -0.001 Acrolein (107028) NA 1.90E+00 0.00E+00 4.04E-02 1.32E-02 80.8 0.0002 Benzene (71432) NA 3.90E+00 0.00E+00 8.29E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 5.95E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.40E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 7.65E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 1.89E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.34E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.40E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.13E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.70E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.34E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.23E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.34E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 1.91E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.70E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 5.53E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.04E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 8.71E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.25E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.55E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.30E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.34E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 7.65E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.32E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 7.01E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.19E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.04E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.49E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 8.93E-03 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 3.61E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 6.59E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.55E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.68E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.82E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 8.29E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.42E+00 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.72E+03 7.29E-02 1.19E-05

Notes:

(1)CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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)CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey.

(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)").

(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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF1_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.071 PRB COAL HEAT INPUT (10^12 BTU/YR) = 0.33 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.628 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 27.50 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW PRB COAL ASH (AS-FIRED) % WT (AVG) 5.30 CY05 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,775 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.35 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 18,585 0.11 1.2 NA AVG OF CY01-CY05 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 1.51E+06 7.12E+04 95.28 11.6 496 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.96E+05 4.84E+04 75.32 7.90 337 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.30E+04 2.56E+04 69.12 4.18 178 NA NA Condensable PM (PM_cond) NA 2.00E+04 3.26 139 NA NA Sulfur dioxide (SO2) NA 6.98E+05 6.28E+05 10.02 16.3 4371 36577 8351 Nitrogen oxides (NOx) NA 9.69E+05 5.31E+05 45.19 59.1 3695 NA NA Carbon monoxide (CO) NA 2.85E+04 2.85E+04 0.00 4.65 198 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 6.27E+03 6.27E+03 0.00 1.02 43.6 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 7.08E+03 2.47E+03 65.18 0.402 17.2 814 -1.2 Ammonia (NH3)(6) NA 5.25E+02 3.94E+00 99.25 6.43E-04 2.74E-02

PM Trace-Element HAP Antimony (Sb) 1.50E-01 1.24E+01 2.74E-01 97.79 4.47E-05 1.91E-03 Arsenic (As) 1.20E+00 9.91E+01 3.54E+00 96.43 5.77E-04 2.46E-02 Beryllium (Be) 2.50E-01 2.07E+01 2.54E-01 98.77 4.14E-05 1.77E-03 Cadmium (Cd) 1.10E-01 9.09E+00 1.08E+00 88.11 1.76E-04 7.52E-03 Chromium (Cr) 4.30E+00 3.55E+02 8.49E+00 97.61 1.39E-03 5.91E-02 Cobalt (Co) 1.60E+00 1.32E+02 2.31E+00 98.25 3.77E-04 1.61E-02 Lead (Pb) 3.20E+00 2.64E+02 8.45E+00 96.81 1.38E-03 5.88E-02 Manganese (Mn) 1.40E+01 1.16E+03 1.82E+01 98.42 2.97E-03 1.27E-01 Nickel (Ni) 2.90E+00 2.40E+02 7.24E+00 96.98 1.18E-03 5.04E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.90E+01 5.86E+03 1.76E+02 97.00 2.87E-02 1.22E+00 57.3 0.04 Hydrogen fluoride (HF) 5.20E+01 4.52E+03 2.71E+02 94.00 4.43E-02 1.89E+00 88.5 0.005 Mercury (Hg) 6.00E-02 4.96E+00 4.69E+00 5.32 7.65E-04 3.27E-02 1.53 -0.001 Selenium (Se) 7.40E-01 6.11E+01 1.83E+00 97.00 2.99E-04 1.28E-02 0.598 0.0002

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 1.45E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 4.24E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 2.45E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.17E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 1.79E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 5.06E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 3.26E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 1.48E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 3.75E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 1.79E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 5.22E-04 2.23E-02 1.04 0.003 Acetophenone (98862) NA 1.20E+00 0.00E+00 1.96E-04 8.35E-03 0.391 0.003 Acrolein (107028) NA 1.90E+00 0.00E+00 3.10E-04 1.32E-02 0.620 0.004 Benzene (71432) NA 3.90E+00 0.00E+00 6.36E-04 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 4.57E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 2.61E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 5.87E-04 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 1.45E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 1.79E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 2.61E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 8.64E-05 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.30E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 1.79E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 9.46E-05 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 1.79E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 1.47E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.30E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 4.24E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 7.99E-05 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 6.69E-07 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 3.26E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 1.96E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 9.95E-05 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 1.79E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 5.87E-04 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.01E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 5.38E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 2.45E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 3.10E-04 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.14E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 6.85E-05 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 2.77E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 5.06E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.19E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.05E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.16E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 6.36E-11 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.09E-02 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.72E+03 5.60E-04 1.19E-05

Notes: (1) CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

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PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.071 COAL HEAT INPUT (10^12 BTU/YR) = 42.83 UNIT 1 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE ILB/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.628 DATE: 07/12/06 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 COAL H2O (AS-FIRED) % WT (AVG) 12.38 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW CY05 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 8.56 ILB/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,467 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 2.66 PM SO2 NOx AVG OF CY01-CY05 PM STACK TEST DATA(4) COAL FIRED TONS 1,866,460 0.11 1.2 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 15.9 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 = 18.63 ILB/PRB WTD-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS SCR operation factor (total) = 0.485 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 1.87E+06 7.12E+04 96.18 1525 496 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.43E+05 4.84E+04 80.03 1037 337 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.03E+05 2.56E+04 75.02 549 178 NA NA Condensable PM (PM_cond) NA 2.00E+04 428 139 QA/QC: NA NA Sulfur dioxide (SO2) NA 4.42E+06 6.28E+05 85.78 13561 4371 0 36577 8351 Nitrogen oxides (NOx) NA 1.43E+06 5.31E+05 62.91 11464 3695 0 NA NA Carbon monoxide (CO) NA 2.18E+04 2.18E+04 0.00 467 152 Volatile organic compounds (VOC) NA 4.79E+03 4.79E+03 0.00 103 33.4 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.33E+05 4.61E+04 65.18 988 321 Ammonia (NH3)(6) NA 4.35E+02 3.43E-02 99.99 7.35E-04 2.39E-04

PM Trace-Element HAP Antimony (Sb) 1.98E+00 1.51E+02 1.16E+00 99.24 2.48E-02 8.06E-03 Arsenic (As) 1.09E+01 8.33E+02 1.80E+01 97.83 3.86E-01 1.26E-01 Beryllium (Be) 1.98E+00 1.51E+02 1.80E+00 98.81 3.86E-02 1.25E-02 Cadmium (Cd) 4.96E-01 3.79E+01 1.98E+00 94.77 4.25E-02 1.38E-02 Chromium (Cr) 1.59E+01 1.21E+03 1.53E+01 98.74 3.28E-01 1.07E-01 Cobalt (Co) 3.68E+00 2.81E+02 3.36E+00 98.81 7.19E-02 2.34E-02 Lead (Pb) 1.39E+01 1.06E+03 2.17E+01 97.96 4.64E-01 1.51E-01 Manganese (Mn) 2.89E+01 2.20E+03 2.36E+01 98.93 5.06E-01 1.64E-01 Nickel (Ni) 1.88E+01 1.44E+03 1.55E+01 98.93 3.31E-01 1.08E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.80E+02 5.34E+04 1.60E+03 97.00 3.44E+01 1.12E+01 Hydrogen fluoride (HF) 9.16E+01 7.37E+03 4.42E+02 94.00 9.48E+00 3.08E+00 Mercury (Hg) 7.98E-02 6.10E+00 2.99E+00 51.02 6.39E-02 2.08E-02 Selenium (Se) 1.69E+00 1.29E+02 1.55E+01 88.02 3.31E-01 1.08E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 1.91E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 5.57E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.21E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.54E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.36E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 6.64E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.28E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 1.95E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 4.93E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.36E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 6.85E-02 2.23E-02 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.57E-02 8.35E-03 Acrolein (107028) NA 1.90E+00 0.00E+00 4.07E-02 1.32E-02 Benzene (71432) NA 3.90E+00 0.00E+00 8.35E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 6.00E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.43E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 7.71E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 1.91E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.36E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.43E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.13E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.71E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.36E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.24E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.36E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 1.93E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.71E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 5.57E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.05E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 8.78E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.28E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.57E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.31E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.36E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 7.71E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.33E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 7.07E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.21E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.07E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.50E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 8.99E-03 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 3.64E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 6.64E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.56E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 2.70E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.84E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 8.35E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.43E+00 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.72E+03 7.35E-02 1.19E-05

Notes: (1) CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF2_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.069 ILB COAL HEAT INPUT (10^12 BTU/YR) = 48.26 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.651 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 12.20 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW ILB COAL ASH (AS-FIRED) % WT (AVG) 8.60 CY05 FUEL & CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,500 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.69 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 2,098,385 0.11 1.2 NA AVG OF CY01-CY05 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 = 18.69 MEDIAN ILB UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS SCR operation factor (total) = 0.489 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 1.87E+06 6.90E+04 96.31 1666 480 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.43E+05 4.69E+04 80.69 1133 327 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.03E+05 2.49E+04 75.83 600 173 NA NA Condensable PM (PM_cond) NA 2.00E+04 483 139 NA NA Sulfur dioxide (SO2) NA 4.44E+06 6.51E+05 85.36 17290 4528 36577 8351 Nitrogen oxides (NOx) NA 1.43E+06 5.31E+05 63.02 14024 3692 NA NA Carbon monoxide (CO) NA 2.17E+04 2.17E+04 0.00 525 151 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 4.78E+03 4.78E+03 0.00 115 33.3 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.34E+05 4.67E+04 65.10 1126 325 3,489,400 -55.0 Ammonia (NH3)(6) NA 4.55E+02 4.55E-03 99.999 1.10E-04 3.17E-05

PM Trace-Element HAP Antimony (Sb) 2.00E+00 1.53E+02 1.14E+00 99.25 2.76E-02 7.95E-03 Arsenic (As) 1.10E+01 8.40E+02 1.77E+01 97.90 4.27E-01 1.23E-01 Beryllium (Be) 2.00E+00 1.53E+02 1.75E+00 98.85 4.22E-02 1.22E-02 Cadmium (Cd) 5.00E-01 3.82E+01 1.96E+00 94.87 4.73E-02 1.36E-02 Chromium (Cr) 1.60E+01 1.22E+03 1.51E+01 98.77 3.64E-01 1.05E-01 Cobalt (Co) 3.70E+00 2.82E+02 3.29E+00 98.83 7.95E-02 2.29E-02 Lead (Pb) 1.40E+01 1.07E+03 2.12E+01 98.01 5.12E-01 1.48E-01 Manganese (Mn) 2.90E+01 2.21E+03 2.32E+01 98.95 5.61E-01 1.62E-01 Nickel (Ni) 1.90E+01 1.45E+03 1.53E+01 98.95 3.69E-01 1.06E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.86E+02 5.38E+04 1.62E+03 97.00 3.90E+01 1.12E+01 77,910 0.05 Hydrogen fluoride (HF) 9.20E+01 7.40E+03 4.44E+02 94.00 1.07E+01 3.09E+00 21,418 0.004 Mercury (Hg) 8.00E-02 6.11E+00 2.96E+00 51.60 7.13E-02 2.06E-02 143 -0.004 Selenium (Se) 1.70E+00 1.30E+02 1.56E+01 88.00 3.76E-01 1.08E-01 752 0.0002

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.15E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 6.27E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.62E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.74E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.65E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 7.48E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.83E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 2.20E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.55E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 2.65E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 7.72E-02 2.23E-02 154 0.0007 Acetophenone (98862) NA 1.20E+00 2.90E-02 8.35E-03 57.9 -0.001 Acrolein (107028) NA 1.90E+00 4.58E-02 1.32E-02 91.7 -0.0006 Benzene (71432) NA 3.90E+00 9.41E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 6.76E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 3.86E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 8.69E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 2.15E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 2.65E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 3.86E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 1.28E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 1.93E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 2.65E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 1.40E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 2.65E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 2.17E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 1.93E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 6.27E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 1.18E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 9.89E-05 2.85E-05 Iodomethane (74884) NA 2.00E+00 4.83E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 2.90E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 1.47E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 2.65E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 8.69E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.50E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 7.96E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.62E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 4.58E-02 1.32E-02 Styrene (100425) NA 7.00E-01 1.69E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.01E-02 2.92E-03 Toluene (108883) NA 1.70E+00 4.10E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 7.48E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 1.76E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 3.04E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.20E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.41E-09 2.71E-09 Organic HAP Total 6.69E+01 1.61E+00 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.66E+03 8.02E-02 1.16E-05

Notes: (1) CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF2_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.069 PRB COAL HEAT INPUT (10^12 BTU/YR) = 0.51 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.651 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 27.50 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW PRB COAL ASH (AS-FIRED) % WT (AVG) 5.30 CY05 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,775 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.35 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 29,233 0.11 1.2 NA AVG OF CY01-CY05 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 1.51E+06 6.90E+04 95.43 17.7 480 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.96E+05 4.69E+04 76.09 12.0 327 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.30E+04 2.49E+04 70.08 6.38 173 NA NA Condensable PM (PM_cond) NA 2.00E+04 5.13 139 NA NA Sulfur dioxide (SO2) NA 6.98E+05 6.51E+05 6.79 28.9 4528 36577 8351 Nitrogen oxides (NOx) NA 9.69E+05 5.31E+05 45.22 101 3692 NA NA Carbon monoxide (CO) NA 2.85E+04 2.85E+04 0.00 7.31 198 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 6.27E+03 6.27E+03 0.00 1.61 43.6 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 7.12E+03 2.48E+03 65.10 0.637 17.3 1284 -0.7 Ammonia (NH3)(6) NA 3.97E+02 2.98E+00 99.25 7.64E-04 2.07E-02

PM Trace-Element HAP Antimony (Sb) 1.50E-01 1.24E+01 2.69E-01 97.83 6.89E-05 1.87E-03 Arsenic (As) 1.20E+00 9.91E+01 3.45E+00 96.52 8.84E-04 2.40E-02 Beryllium (Be) 2.50E-01 2.07E+01 2.45E-01 98.81 6.29E-05 1.71E-03 Cadmium (Cd) 1.10E-01 9.09E+00 1.06E+00 88.30 2.73E-04 7.40E-03 Chromium (Cr) 4.30E+00 3.55E+02 8.34E+00 97.65 2.14E-03 5.80E-02 Cobalt (Co) 1.60E+00 1.32E+02 2.26E+00 98.29 5.80E-04 1.57E-02 Lead (Pb) 3.20E+00 2.64E+02 8.24E+00 96.89 2.11E-03 5.73E-02 Manganese (Mn) 1.40E+01 1.16E+03 1.79E+01 98.45 4.59E-03 1.24E-01 Nickel (Ni) 2.90E+00 2.40E+02 7.14E+00 97.02 1.83E-03 4.97E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.90E+01 5.86E+03 1.76E+02 97.00 4.51E-02 1.22E+00 90.2 0.04 Hydrogen fluoride (HF) 5.20E+01 4.52E+03 2.71E+02 94.00 6.96E-02 1.89E+00 139.3 0.004 Mercury (Hg) 6.00E-02 4.96E+00 4.69E+00 5.32 1.20E-03 3.27E-02 2.41 -0.001 Selenium (Se) 7.40E-01 6.11E+01 1.83E+00 97.00 4.71E-04 1.28E-02 0.941 -0.0003

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.28E-04 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 6.67E-04 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.85E-04 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.85E-04 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.82E-04 7.65E-03 2-Butanone (78933) NA 3.10E+00 7.95E-04 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 5.13E-05 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 2.33E-03 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.90E-04 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 2.82E-04 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 8.21E-04 2.23E-02 1.64 0.001 Acetophenone (98862) NA 1.20E+00 3.08E-04 8.35E-03 0.616 0.004 Acrolein (107028) NA 1.90E+00 4.87E-04 1.32E-02 0.975 0.003 Benzene (71432) NA 3.90E+00 1.00E-03 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 7.18E-05 1.95E-03 Biphenyl (92524) NA 1.60E-01 4.10E-05 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 9.23E-04 2.51E-02 Bromomethane (74839) NA 8.90E-01 2.28E-04 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 2.82E-04 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 4.10E-05 1.11E-03 Chloroethane (75003) NA 5.30E-01 1.36E-04 3.69E-03 Chloroform (67663) NA 8.00E-01 2.05E-04 5.57E-03 Chloromethane (74873) NA 1.10E+00 2.82E-04 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 1.49E-04 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 2.82E-05 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 2.31E-05 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 2.05E-04 5.57E-03 Formaldehyde (50000) NA 2.60E+00 6.67E-04 1.81E-02 n-Hexane (110543) NA 4.90E-01 1.26E-04 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.05E-06 2.85E-05 Iodomethane (74884) NA 2.00E+00 5.13E-04 1.39E-02 Isophorone (78591) NA 1.20E+00 3.08E-04 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 1.56E-04 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 2.82E-04 7.65E-03 Methylene chloride (75092) NA 3.60E+00 9.23E-04 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.59E-04 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 8.47E-04 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.85E-06 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 4.87E-04 1.32E-02 Styrene (100425) NA 7.00E-01 1.80E-04 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.08E-04 2.92E-03 Toluene (108883) NA 1.70E+00 4.36E-04 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 7.95E-05 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 1.87E-04 5.08E-03 Xylenes (1330207) NA 1.26E+00 3.23E-04 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.40E-04 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 1.00E-10 2.71E-09 Organic HAP Total 6.69E+01 1.72E-02 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.66E+03 8.53E-04 1.16E-05

Notes: (1) CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF2

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.069 COAL HEAT INPUT (10^12 BTU/YR) = 48.78 UNIT 2 RATED CAPACITY 10^6 BTU/HR 6,959 CY05 ROUTINE ILB/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 0.651 DATE: 07/12/06 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.531 COAL H2O (AS-FIRED) % WT (AVG) 12.38 AIR POLLUTION CONTROL SYSTEM(S): VENTURI-FGDW CY05 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 8.56 ILB/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,467 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 2.66 PM SO2 NOx AVG OF CY01-CY05 PM STACK TEST DATA(4) COAL FIRED TONS 2,127,618 0.11 1.2 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 15.9 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 = 18.63 ILB/PRB WTD-AVG UNCONTROLLED CONTROLLED ESTIMATED EMISSIONS SCR operation factor (total) = 0.489 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 1.87E+06 6.90E+04 96.30 1684 480 3353 765 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.43E+05 4.69E+04 80.65 1145 327 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.03E+05 2.49E+04 75.79 606 173 NA NA Condensable PM (PM_cond) NA 2.00E+04 488 139 QA/QC: NA NA Sulfur dioxide (SO2) NA 4.40E+06 6.51E+05 85.23 17319 4528 0 36577 8351 Nitrogen oxides (NOx) NA 1.43E+06 5.31E+05 62.89 14124 3692 0 NA NA Carbon monoxide (CO) NA 2.18E+04 2.18E+04 0.00 532 152 Volatile organic compounds (VOC) NA 4.80E+03 4.80E+03 0.00 117 33.4 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.32E+05 4.62E+04 65.10 1126 321 Ammonia (NH3)(6) NA 4.54E+02 3.58E-02 99.99 8.74E-04 2.49E-04

PM Trace-Element HAP Antimony (Sb) 1.98E+00 1.51E+02 1.13E+00 99.25 2.76E-02 7.88E-03 Arsenic (As) 1.09E+01 8.33E+02 1.75E+01 97.90 4.27E-01 1.22E-01 Beryllium (Be) 1.98E+00 1.51E+02 1.73E+00 98.85 4.23E-02 1.21E-02 Cadmium (Cd) 4.96E-01 3.79E+01 1.95E+00 94.86 4.75E-02 1.36E-02 Chromium (Cr) 1.59E+01 1.21E+03 1.50E+01 98.76 3.66E-01 1.04E-01 Cobalt (Co) 3.68E+00 2.81E+02 3.28E+00 98.83 8.01E-02 2.28E-02 Lead (Pb) 1.39E+01 1.06E+03 2.11E+01 98.01 5.14E-01 1.47E-01 Manganese (Mn) 2.89E+01 2.20E+03 2.32E+01 98.95 5.65E-01 1.61E-01 Nickel (Ni) 1.88E+01 1.44E+03 1.52E+01 98.94 3.71E-01 1.06E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.80E+02 5.34E+04 1.60E+03 97.00 3.90E+01 1.11E+01 Hydrogen fluoride (HF) 9.16E+01 7.37E+03 4.42E+02 94.00 1.08E+01 3.08E+00 Mercury (Hg) 7.98E-02 6.10E+00 2.97E+00 51.22 7.25E-02 2.07E-02 Selenium (Se) 1.69E+00 1.29E+02 1.54E+01 88.05 3.76E-01 1.07E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 0.00E+00 2.17E-02 6.19E-03 1,2-Dibromoethane (106934) NA 2.60E+00 0.00E+00 6.34E-02 1.81E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 0.00E+00 3.66E-02 1.04E-02 1,3-Dichloropropene (542756) NA 7.20E-01 0.00E+00 1.76E-02 5.01E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 0.00E+00 2.68E-02 7.65E-03 2-Butanone (78933) NA 3.10E+00 0.00E+00 7.56E-02 2.16E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 0.00E+00 4.88E-03 1.39E-03 3-Chloropropylene (107051) NA 9.10E+00 0.00E+00 2.22E-01 6.33E-02 4-Methyl-2-pentanone (108101) NA 2.30E+00 0.00E+00 5.61E-02 1.60E-02 4-Methylphenol (106445) NA 1.10E+00 0.00E+00 2.68E-02 7.65E-03 Acetaldehyde (75070) NA 3.20E+00 0.00E+00 7.80E-02 2.23E-02 Acetophenone (98862) NA 1.20E+00 0.00E+00 2.93E-02 8.35E-03 Acrolein (107028) NA 1.90E+00 0.00E+00 4.63E-02 1.32E-02 Benzene (71432) NA 3.90E+00 0.00E+00 9.51E-02 2.71E-02 Benzyl chloride (100447) NA 2.80E-01 0.00E+00 6.83E-03 1.95E-03 Biphenyl (92524) NA 1.60E-01 0.00E+00 3.90E-03 1.11E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 0.00E+00 8.78E-02 2.51E-02 Bromomethane (74839) NA 8.90E-01 0.00E+00 2.17E-02 6.19E-03 Carbon disulfide (75150) NA 1.10E+00 0.00E+00 2.68E-02 7.65E-03 Chlorobenzene (108907) NA 1.60E-01 0.00E+00 3.90E-03 1.11E-03 Chloroethane (75003) NA 5.30E-01 0.00E+00 1.29E-02 3.69E-03 Chloroform (67663) NA 8.00E-01 0.00E+00 1.95E-02 5.57E-03 Chloromethane (74873) NA 1.10E+00 0.00E+00 2.68E-02 7.65E-03 Dibenzofuran (132649) NA 5.80E-01 0.00E+00 1.41E-02 4.04E-03 Dibutylphthalate (84742) NA 1.10E-01 0.00E+00 2.68E-03 7.65E-04 Dimethylphthalate (131113) NA 9.00E-02 0.00E+00 2.19E-03 6.26E-04 Ethyl benzene (100414) NA 8.00E-01 0.00E+00 1.95E-02 5.57E-03 Formaldehyde (50000) NA 2.60E+00 0.00E+00 6.34E-02 1.81E-02 n-Hexane (110543) NA 4.90E-01 0.00E+00 1.20E-02 3.41E-03 Hexachlorobenzene (118741) NA 4.10E-03 0.00E+00 1.00E-04 2.85E-05 Iodomethane (74884) NA 2.00E+00 0.00E+00 4.88E-02 1.39E-02 Isophorone (78591) NA 1.20E+00 0.00E+00 2.93E-02 8.35E-03 Methyl chloroform (71556) NA 6.10E-01 0.00E+00 1.49E-02 4.24E-03 Methyl methacrylate (80626) NA 1.10E+00 0.00E+00 2.68E-02 7.65E-03 Methylene chloride (75092) NA 3.60E+00 0.00E+00 8.78E-02 2.51E-02 Naphthalene (91203) 1.60E+00 6.20E-01 0.00E+00 1.51E-02 4.31E-03 Phenol (108952) 1.20E+01 3.30E+00 0.00E+00 8.05E-02 2.30E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.66E-04 1.04E-04 Propionaldehyde (123386) NA 1.90E+00 0.00E+00 4.63E-02 1.32E-02 Styrene (100425) NA 7.00E-01 0.00E+00 1.71E-02 4.87E-03 Tetrachloroethylene (127184) NA 4.20E-01 0.00E+00 1.02E-02 2.92E-03 Toluene (108883) NA 1.70E+00 0.00E+00 4.15E-02 1.18E-02 Vinyl acetate (108054) NA 3.10E-01 0.00E+00 7.56E-03 2.16E-03 Vinyl chloride (75014) NA 7.30E-01 0.00E+00 1.78E-02 5.08E-03 Xylenes (1330207) NA 1.26E+00 0.00E+00 3.07E-02 8.77E-03 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.23E-02 9.22E-03 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.51E-09 2.71E-09 Organic HAP Total 6.69E+01 0.00E+00 1.63E+00 4.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 1.66E+03 8.11E-02 1.16E-05

Notes: (1) CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF3_ILB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.035 ILB COAL HEAT INPUT (10^12 BTU/YR) = 17.14 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY05 ROUTINE ILLINOIS-BASIN (ILB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 2.31 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.444 BASED ON: ILB COAL H2O (AS-FIRED) % WT (AVG) 12.20 AIR POLLUTION CONTROL SYSTEM(S): ESPC ILB COAL ASH (AS-FIRED) % WT (AVG) 8.60 CY05 FUEL & CEMS DATA(1) ILB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 11,500 ALLOWABLE EMISSION RATES (LB/10^6 BTU): ILB TRACE-ELEMENT CONCENTRATNS(2) ILB COAL SULFUR (AS-FIRED) % WT (AVG) 2.69 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) ILB COAL FIRED (AS-FIRED) TONS 745,146 0.11 5.4 NA AVG OF CY01-CY05 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 1.87E+06 3.52E+04 98.12 302 403 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.43E+05 2.39E+04 90.15 205 274 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 1.03E+05 1.27E+04 87.68 109 145 NA NA Condensable PM (PM_cond) NA 2.39E+05 2048 2738 NA NA Sulfur dioxide (SO2) NA 4.44E+06 4.44E+06 0.00 41376 50919 270981 61868 Nitrogen oxides (NOx) NA 1.43E+06 4.44E+05 69.04 4549 5090 NA NA Carbon monoxide (CO) NA 2.17E+04 2.17E+04 0.00 186 249 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 4.78E+03 4.78E+03 0.00 41.0 54.8 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 1.36E+05 8.90E+04 34.55 763 1020 1,522,100 0.2 Ammonia (NH3)(6) NA 5.43E+02 5.43E-01 99.90 4.66E-03 6.22E-03

PM Trace-Element HAP Antimony (Sb) 2.00E+00 1.53E+02 7.47E-01 99.51 6.40E-03 8.56E-03 Arsenic (As) 1.10E+01 8.40E+02 9.97E+00 98.81 8.54E-02 1.14E-01 Beryllium (Be) 2.00E+00 1.53E+02 8.34E-01 99.45 7.15E-03 9.56E-03 Cadmium (Cd) 5.00E-01 3.82E+01 1.40E+00 96.34 1.20E-02 1.60E-02 Chromium (Cr) 1.60E+01 1.22E+03 1.02E+01 99.16 8.74E-02 1.17E-01 Cobalt (Co) 3.70E+00 2.82E+02 2.07E+00 99.27 1.77E-02 2.37E-02 Lead (Pb) 1.40E+01 1.07E+03 1.24E+01 98.84 1.06E-01 1.42E-01 Manganese (Mn) 2.90E+01 2.21E+03 1.55E+01 99.30 1.33E-01 1.78E-01 Nickel (Ni) 1.90E+01 1.45E+03 1.11E+01 99.24 9.48E-02 1.27E-01

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.86E+02 5.38E+04 5.38E+04 0.00 4.61E+02 6.17E+02 922,210 0.05 Hydrogen fluoride (HF) 9.20E+01 7.40E+03 6.66E+03 10.00 5.70E+01 7.63E+01 114,080 0.008 Mercury (Hg) 8.00E-02 6.11E+00 4.72E+00 22.65 4.05E-02 5.41E-02 81.0 0.02 Selenium (Se) 1.70E+00 1.30E+02 7.14E+01 45.00 6.12E-01 8.18E-01 1,223 0.002

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 7.63E-03 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 2.23E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 1.29E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 6.17E-03 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 9.43E-03 1.26E-02 2-Butanone (78933) NA 3.10E+00 2.66E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 1.71E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 7.80E-02 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 1.97E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 9.43E-03 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 2.74E-02 3.67E-02 54.8 -0.0005 Acetophenone (98862) NA 1.20E+00 1.03E-02 1.37E-02 20.6 0.0001 Acrolein (107028) NA 1.90E+00 1.63E-02 2.18E-02 32.6 -0.0004 Benzene (71432) NA 3.90E+00 3.34E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 2.40E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 1.37E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 3.08E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 7.63E-03 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 9.43E-03 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 1.37E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 4.54E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 6.86E-03 9.17E-03 Chloromethane (74873) NA 1.10E+00 9.43E-03 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 4.97E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 9.43E-04 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 7.71E-04 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 6.86E-03 9.17E-03 Formaldehyde (50000) NA 2.60E+00 2.23E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 4.20E-03 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 3.51E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 1.71E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 1.03E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 5.23E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 9.43E-03 1.26E-02 Methylene chloride (75092) NA 3.60E+00 3.08E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 5.31E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 2.83E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 1.29E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 1.63E-02 2.18E-02 Styrene (100425) NA 7.00E-01 6.00E-03 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 3.60E-03 4.81E-03 Toluene (108883) NA 1.70E+00 1.46E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 2.66E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 6.26E-03 8.36E-03 Xylenes (1330207) NA 1.26E+00 1.08E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 1.14E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 3.34E-09 4.47E-09 Organic HAP Total 6.69E+01 5.73E-01 7.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 8.48E+02 1.45E-02 9.71E-06

Notes:

(1)CY05 unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al., along with PAF coal-region proximate coal-quality data; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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)CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey.

(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)").

(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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF3_PRB

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.035 PRB COAL HEAT INPUT (10^12 BTU/YR) = 32.02 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY05 ROUTINE POWDER RIVER BASIN (PRB) SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 2.31 DATE: 07/12/06 COAL-FIRED AIR EMISSION ESTIMATES NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.444 BASED ON: PRB COAL H2O (AS-FIRED) % WT (AVG) 27.50 AIR POLLUTION CONTROL SYSTEM(S): ESPC PRB COAL ASH (AS-FIRED) % WT (AVG) 5.30 CY05 FUEL & CEMS DATA(1) PRB COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 8,775 ALLOWABLE EMISSION RATES (LB/10^6 BTU): PRB TRACE-ELEMENT CONCENTRATNS(2) PRB COAL SULFUR (AS-FIRED) % WT (AVG) 0.35 PM SO2 NOx MEDIAN EFH HAP EMISSN FACTRS(3) PRB COAL FIRED (AS-FIRED) TONS 1,824,322 0.11 5.4 NA AVG OF CY01-CY05 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 1.51E+06 3.52E+04 97.67 563 403 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 1.96E+05 2.39E+04 87.81 383 274 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.30E+04 1.27E+04 84.74 203 145 NA NA Condensable PM (PM_cond) NA 1.00E+04 160 115 NA NA Sulfur dioxide (SO2) NA 6.98E+05 6.98E+05 0.00 12140 7997 270981 61868 Nitrogen oxides (NOx) NA 9.69E+05 4.44E+05 54.14 5737 5090 NA NA Carbon monoxide (CO) NA 2.85E+04 2.85E+04 0.00 456 326 Comparison w/ 4-28-06 LT Outputs: Volatile organic compounds (VOC) NA 6.27E+03 6.27E+03 0.00 100 71.8 Air rel, lb/yr % Difference Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 4.84E+03 2.18E+03 55.00 34.9 25.0 65,007 6.9 Ammonia (NH3)(6) NA 5.43E+02 4.07E+02 25.00 6.52 4.67

PM Trace-Element HAP Antimony (Sb) 1.50E-01 1.24E+01 1.76E-01 98.58 2.81E-03 2.01E-03 Arsenic (As) 1.20E+00 9.91E+01 1.94E+00 98.04 3.11E-02 2.23E-02 Beryllium (Be) 2.50E-01 2.07E+01 1.17E-01 99.43 1.87E-03 1.34E-03 Cadmium (Cd) 1.10E-01 9.09E+00 7.59E-01 91.64 1.22E-02 8.70E-03 Chromium (Cr) 4.30E+00 3.55E+02 5.64E+00 98.41 9.03E-02 6.47E-02 Cobalt (Co) 1.60E+00 1.32E+02 1.42E+00 98.93 2.27E-02 1.63E-02 Lead (Pb) 3.20E+00 2.64E+02 4.80E+00 98.18 7.69E-02 5.50E-02 Manganese (Mn) 1.40E+01 1.16E+03 1.19E+01 98.97 1.91E-01 1.37E-01 Nickel (Ni) 2.90E+00 2.40E+02 5.16E+00 97.84 8.27E-02 5.92E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 6.90E+01 5.86E+03 1.17E+03 80.00 1.88E+01 1.34E+01 37,510 0.04 Hydrogen fluoride (HF) 5.20E+01 4.52E+03 2.26E+03 50.00 3.62E+01 2.59E+01 72,422 0.005 Mercury (Hg) 6.00E-02 4.96E+00 4.16E+00 16.14 6.66E-02 4.76E-02 133 0.02 Selenium (Se) 7.40E-01 6.11E+01 1.83E+00 97.00 2.94E-02 2.10E-02 58.7 -0.0001

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 1.42E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 4.16E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 2.40E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.15E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 1.76E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 4.96E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 3.20E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 1.46E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 3.68E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 1.76E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 5.12E-02 3.67E-02 102 0.004 Acetophenone (98862) NA 1.20E+00 1.92E-02 1.37E-02 38.4 0.003 Acrolein (107028) NA 1.90E+00 3.04E-02 2.18E-02 60.8 0.003 Benzene (71432) NA 3.90E+00 6.24E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 4.48E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 2.56E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 5.76E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 1.42E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 1.76E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 2.56E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 8.48E-03 6.07E-03 Chloroform (67663) NA 8.00E-01 1.28E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 1.76E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 9.28E-03 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 1.76E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 1.44E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.28E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 4.16E-02 2.98E-02 83.2 0.003 n-Hexane (110543) NA 4.90E-01 7.84E-03 5.61E-03 15.7 0.002 Hexachlorobenzene (118741) NA 4.10E-03 6.56E-05 4.70E-05 Iodomethane (74884) NA 2.00E+00 3.20E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 1.92E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 9.77E-03 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 1.76E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 5.76E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 9.93E-03 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 5.28E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 2.40E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 3.04E-02 2.18E-02 Styrene (100425) NA 7.00E-01 1.12E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 6.72E-03 4.81E-03 Toluene (108883) NA 1.70E+00 2.72E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 4.96E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.17E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 2.02E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 2.12E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 6.24E-09 4.47E-09 Organic HAP Total 6.69E+01 1.07E+00 7.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 8.48E+02 2.71E-02 9.71E-06

Notes: (1) CY05 unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al., along with PAF coal-region proximate coal-quality data; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1PAF3

PARADISE FOSSIL PLANT PARTICULATE EMISSION (TEST) LB/10^6 BTU 0.035 COAL HEAT INPUT (10^12 BTU/YR) = 49.16 UNIT 3 RATED CAPACITY 10^6 BTU/HR 11,457 CY05 ROUTINE ILB/PRB COAL-FIRED SO2 EMISSIONS (CEMS AVG) LB/10^6 BTU 2.31 DATE: 07/12/06 AIR EMISSION ESTIMATES BASED ON: NOx EMISSIONS (CEMS AVG) LB/10^6 BTU 0.444 COAL H2O (AS-FIRED) % WT (AVG) 23.06 AIR POLLUTION CONTROL SYSTEM(S): ESPC CY05 FUEL & CEMS DATA(1) COAL ASH (AS-FIRED) % WT (AVG) 6.26 ILB/PRB TRACE-ELEMENT CONCENTRATNS(2) COAL HEAT VALUE (AS-FIRED) BTU/LB (AVG) 9,565 ALLOWABLE EMISSION RATES (LB/10^6 BTU): MEDIAN EFH HAP EMISSN FACTRS(3) COAL SULFUR (AS-FIRED) % WT (AVG) 1.03 PM SO2 NOx AVG OF CY01-CY05 PM STACK TEST DATA(4) COAL FIRED TONS 2,569,468 0.11 5.4 NA ASH SPLIT TO BOTTOM % 75 STACK-EXIT SO3 CONCENTRATN PPM VOL 11.2 VOC & ORGANIC HAP CONTRL EFFCNCY (%): 0.0

MEDIAN EFH HOURLY ILB/PRB WTD-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 1.64E+06 3.52E+04 97.85 865 403 5520 1260 PM < 10-micrometer aero. diam. (PM10_fil) NA 2.13E+05 2.39E+04 88.74 588 274 NA NA PM < 2.5-micrometer aero. diam. (PM2.5_fil) NA 8.99E+04 1.27E+04 85.91 311 145 NA NA Condensable PM (PM_cond) NA 8.98E+04 2208 1029 QA/QC: NA NA Sulfur dioxide (SO2) NA 2.31E+06 2.31E+06 0.00 53516 26477 0 270981 61868 Nitrogen oxides (NOx) NA 1.13E+06 4.44E+05 60.72 10286 5090 0 NA NA Carbon monoxide (CO) NA 2.61E+04 2.61E+04 0.00 642 299 Volatile organic compounds (VOC) NA 5.75E+03 5.75E+03 0.00 141 65.9 Sulfuric acid (SO3/H2SO4) as H2SO4(5) NA 5.37E+04 3.25E+04 39.57 798 372 Ammonia (NH3)(6) NA 5.43E+02 2.66E+02 51.11 6.53 3.04

PM Trace-Element HAP Antimony (Sb) 7.62E-01 6.13E+01 3.75E-01 99.39 9.22E-03 4.30E-03 Arsenic (As) 4.44E+00 3.57E+02 4.74E+00 98.67 1.17E-01 5.43E-02 Beryllium (Be) 8.29E-01 6.67E+01 3.67E-01 99.45 9.02E-03 4.21E-03 Cadmium (Cd) 2.39E-01 1.92E+01 9.82E-01 94.89 2.41E-02 1.13E-02 Chromium (Cr) 8.17E+00 6.57E+02 7.23E+00 98.90 1.78E-01 8.29E-02 Cobalt (Co) 2.29E+00 1.85E+02 1.65E+00 99.11 4.05E-02 1.89E-02 Lead (Pb) 6.77E+00 5.45E+02 7.45E+00 98.63 1.83E-01 8.53E-02 Manganese (Mn) 1.90E+01 1.53E+03 1.32E+01 99.14 3.24E-01 1.51E-01 Nickel (Ni) 8.23E+00 6.62E+02 7.22E+00 98.91 1.77E-01 8.27E-02

Gaseous Trace-Element HAP Hydrogen chloride (HCl) 2.73E+02 2.26E+04 1.95E+04 13.52 4.80E+02 2.24E+02 Hydrogen fluoride (HF) 6.52E+01 5.53E+03 3.79E+03 31.33 9.33E+01 4.35E+01 Mercury (Hg) 6.66E-02 5.36E+00 4.36E+00 18.72 1.07E-01 4.99E-02 Selenium (Se) 1.06E+00 8.51E+01 2.61E+01 69.34 6.41E-01 2.99E-01

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) NA 8.90E-01 2.19E-02 1.02E-02 1,2-Dibromoethane (106934) NA 2.60E+00 6.39E-02 2.98E-02 1,2,4-Trichlorobenzene (120821) NA 1.50E+00 3.69E-02 1.72E-02 1,3-Dichloropropene (542756) NA 7.20E-01 1.77E-02 8.25E-03 1,4-Dichlorobenzene (106467) NA 1.10E+00 2.70E-02 1.26E-02 2-Butanone (78933) NA 3.10E+00 7.62E-02 3.55E-02 2,4-Dinitrotoluene (121142) NA 2.00E-01 4.92E-03 2.29E-03 3-Chloropropylene (107051) NA 9.10E+00 2.24E-01 1.04E-01 4-Methyl-2-pentanone (108101) NA 2.30E+00 5.65E-02 2.64E-02 4-Methylphenol (106445) NA 1.10E+00 2.70E-02 1.26E-02 Acetaldehyde (75070) NA 3.20E+00 7.86E-02 3.67E-02 Acetophenone (98862) NA 1.20E+00 2.95E-02 1.37E-02 Acrolein (107028) NA 1.90E+00 4.67E-02 2.18E-02 Benzene (71432) NA 3.90E+00 9.59E-02 4.47E-02 Benzyl chloride (100447) NA 2.80E-01 6.88E-03 3.21E-03 Biphenyl (92524) NA 1.60E-01 3.93E-03 1.83E-03 bis(2-Ethylhexyl)phthalate (117817) 6.65E-01 3.60E+00 8.85E-02 4.12E-02 Bromomethane (74839) NA 8.90E-01 2.19E-02 1.02E-02 Carbon disulfide (75150) NA 1.10E+00 2.70E-02 1.26E-02 Chlorobenzene (108907) NA 1.60E-01 3.93E-03 1.83E-03 Chloroethane (75003) NA 5.30E-01 1.30E-02 6.07E-03 Chloroform (67663) NA 8.00E-01 1.97E-02 9.17E-03 Chloromethane (74873) NA 1.10E+00 2.70E-02 1.26E-02 Dibenzofuran (132649) NA 5.80E-01 1.43E-02 6.65E-03 Dibutylphthalate (84742) NA 1.10E-01 2.70E-03 1.26E-03 Dimethylphthalate (131113) NA 9.00E-02 2.21E-03 1.03E-03 Ethyl benzene (100414) NA 8.00E-01 1.97E-02 9.17E-03 Formaldehyde (50000) NA 2.60E+00 6.39E-02 2.98E-02 n-Hexane (110543) NA 4.90E-01 1.20E-02 5.61E-03 Hexachlorobenzene (118741) NA 4.10E-03 1.01E-04 4.70E-05 Iodomethane (74884) NA 2.00E+00 4.92E-02 2.29E-02 Isophorone (78591) NA 1.20E+00 2.95E-02 1.37E-02 Methyl chloroform (71556) NA 6.10E-01 1.50E-02 6.99E-03 Methyl methacrylate (80626) NA 1.10E+00 2.70E-02 1.26E-02 Methylene chloride (75092) NA 3.60E+00 8.85E-02 4.12E-02 Naphthalene (91203) 1.60E+00 6.20E-01 1.52E-02 7.10E-03 Phenol (108952) 1.20E+01 3.30E+00 8.11E-02 3.78E-02 Polychlorinated biphenyl [PCB] (1336363) NA 1.50E-02 0.00E+00 3.69E-04 1.72E-04 Propionaldehyde (123386) NA 1.90E+00 4.67E-02 2.18E-02 Styrene (100425) NA 7.00E-01 1.72E-02 8.02E-03 Tetrachloroethylene (127184) NA 4.20E-01 1.03E-02 4.81E-03 Toluene (108883) NA 1.70E+00 4.18E-02 1.95E-02 Vinyl acetate (108054) NA 3.10E-01 7.62E-03 3.55E-03 Vinyl chloride (75014) NA 7.30E-01 1.79E-02 8.36E-03 Xylenes (1330207) NA 1.26E+00 3.10E-02 1.44E-02 Polycyclic organic matter (POM) NA 1.32E+00 0.00E+00 3.26E-02 1.52E-02 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) NA 3.90E-07 0.00E+00 9.59E-09 4.47E-09 Organic HAP Total 6.69E+01 1.64E+00 7.66E-01 pCi/gram of PM pCi/10^6 Btu Ci/yr Ci/hr Radionuclides 53.1 8.48E+02 4.17E-02 9.71E-06

Notes: (1) CY05 unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al., along with PAF coal-region proximate coal-quality data; CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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) CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (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)"). (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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

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 EMISSION FACTOR (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, % 17.4 1.73E-04 LB/T 100T/HR 8.64E-05 1.73E-02 NONE 0 8.64E-05 1.73E-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, % 17.4 1.73E-04 LB/T 1000T/HR 2.16E-02 1.73E-01 PARTIAL 50 1.08E-02 8.64E-02 EMISSION TO SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR ENCLOSURE SOURCE SURGE HOPPER FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.16E-02 1.73E-01 ENCLOSURE 70 6.49E-03 5.18E-02 TO BC-3 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR
**EMISSIONS SUB-TOTAL 4.33E-02**  **3.45E-01 1.73E-02**  **1.38E-01**

INSIGNIF. BUNKERS BC-16 , BC-17, BC--26 OR CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 5.47E-01 1.73E-01 ENCLOSURE 70 1.64E-01 5.18E-02 EMISSION BC--27 FEED TO BUNKERS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR SOURCE 19 TRACTOR TRUCK COAL HAULING UNPAVED ROAD SILT CONTENT, % 9.6 30.20 LB/VMT 4300T/HR 3.20E+03 7.55E+03 WET 95 1.60E+02 3.77E+02

UNLOADING ONE-WAY FULL FUGITIVE DUST VEHICLE SPEED, MPH 20 3.64E+06 T/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 1.30E+03 3.08E+03 WET 95 6.51E+01 1.54E+02 ONE-WAY EMPTY FUGITIVE DUST VEHICLE SPEED, MPH 20 3.64E+06 T/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, % 17.4 1.73E-04 LB/T 4300T/HR 3.14E-01 7.43E-01 NONE 0 3.14E-01 7.43E-01 SHORT-TERM STORAGE PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.64E+06 T/YR

FRONT-END LOADER UNPAVED ROAD SILT CONTENT, % 4 0.79 LB/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+03 MILES/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, % 17.4 1.73E-04 LB/T 4300T/HR 3.14E-01 7.43E-01 NONE 0 3.14E-01 7.43E-01 FEED TO SHORT-TERM PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.64E+06 T/YR
OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49 LB/ACRE-D 2.1 ACRE 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, % 17.4 1.73E-04 LB/T 2000T/HR 3.14E-01 3.45E-01 PARTIAL 50 1.57E-01 1.73E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.64E+06 T/YR ENCLOSURE HOPPER #1 OR #2 TRUCK HOPPER #1 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 70 4.72E-02 5.18E-02 FEED TO BC-1 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR
TRUCK HOPPER #2 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 70 4.72E-02 5.18E-02 FEED TO BC-2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR
**EMISSIONS SUB-TOTAL 5.11E+03**  **1.10E+04 2.60E+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 EMISSION FACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 20 BREAKER BC-1 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 97 4.72E-03 5.18E-03

BUILDING BREAKER NO. 1 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR FOAM (BREAKERS NO. 1 & 2) SUPPRESSION BC-2 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 97 4.72E-03 5.18E-03 BREAKER NO. 2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR FOAM SUPPRESSION BREAKER NO. 1 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 1.82E+01 2.00E+01 ENCLOSURE 97 5.46E-01 6.00E-01 (AP-42 SEC. 8.23) 1.82E+06 T/YR FOAM SUPPRESSION BREAKER NO. 2 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 1.82E+01 2.00E+01 ENCLOSURE 97 5.46E-01 6.00E-01 (AP-42 SEC. 8.23) 1.82E+06 T/YR FOAM SUPPRESSION BREAKERS FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 94 9.43E-03 1.04E-02 TO BC-7 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR FOAM 1ST CARRYOVER BREAKERS FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.57E-01 1.73E-01 ENCLOSURE 94 9.43E-03 1.04E-02 TO BC-8 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.82E+06 T/YR FOAM 1ST CARRYOVER BREAKERS FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 100T/HR 8.64E-05 1.73E-02 ENCLOSURE 94 5.18E-06 1.04E-03 BC-20 (REFUSE CONV) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03 T/YR FOAM 1ST CARRYOVER BC-20 (REFUSE CONV) CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 100T/HR 8.64E-05 1.73E-02 PARTIAL 85 1.30E-05 2.59E-03 FEED TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03 T/YR ENCLOSURE FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 3.70E+01**  **4.07E+01 1.12E+00**  **1.23E+00**

21 BREAKER BUILDING BC-3 FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.16E-02 1.73E-01 ENCLOSURE 97 6.49E-04 5.18E-03

(BREAKER NO. 3) TO BREAKER NO.3 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR FOAM SUPPRESSION BREAKER No. 3 PRIMARY CRUSHER

--- --- 0.02LB/T 1000T/HR 2.51E+00 2.00E+01 ENCLOSURE 97 7.52E-02 6.00E-01 (AP-42 SEC. 8.23) 2.51E+05 T/YR FOAM SUPPRESSION BREAKER NO.3 FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.16E-02 1.73E-01 ENCLOSURE 94 1.30E-03 1.04E-02 TO BC-4 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR FOAM 1ST CARRYOVER BREAKER NO.3 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 100T/HR 4.32E-05 1.73E-02 PARTIAL 90 4.32E-06 1.73E-03 RC-1 (REFUSE CONV) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.00E+02 T/YR ENCLOSURE FOAM 1ST CARRYOVER **EMISSIONS SUB-TOTAL 2.55E+00**  **2.04E+01 7.71E-02**  **6.17E-01**

22 TRANSFER STN A BC-7 AND BC-8 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 3.14E-01 3.45E-01 ENCLOSURE 91 2.83E-02 3.11E-02 BC-9, BC-12, BC-19, OR BC-31 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.64E+06 T/YR FOAM 2ND CARRYOVER BC-45 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 3.68E-02 3.45E-01 ENCLOSURE 70 1.11E-02 1.04E-01 BC-9, BC-12 OR BC-19 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR
BC-18 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 1.79E-01 3.45E-01 ENCLOSURE 94 1.07E-02 2.07E-02 BC-9 OR BC-12 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.07E+06 T/YR FOAM 1ST CARRYOVER SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 2.55E+00 T/HR 1.16E-01 1.27E-01 ENCLOSURE 70 3.48E-02 3.82E-02 BC-7 AND BC-8 SAMPLER (AP-42, SEC. 8.23) 4.64E+03 T/YR
**EMISSIONS SUB-TOTAL 6.46E-01**  **1.16E+00 8.49E-02**  **1.94E-01**

23 TRANSFER BC-4 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.16E-02 1.73E-01 ENCLOSURE 91 1.95E-03 1.55E-02

STATION B BC-28 OR BC-44 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR FOAM 2ND CARRYOVER BC-30 FEED TO BC-44 CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/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+00 T/YR
BC-43A TO BC-28 CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/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+00 T/YR
SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 1.5T/HR 9.40E-03 7.50E-02 ENCLOSURE 70 2.82E-03 2.25E-02 BC-4 SAMPLER (AP-42, SEC. 8.23) 3.76E+02 T/YR
**EMISSIONS SUB-TOTAL 3.10E-02**  **1.23E+00 4.77E-03**  **3.33E-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 EMISSION FACTOR (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-04 LB/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+00 T/YR ENCLOSURE LIVE PILE No. 3 & 4 BC-28 FEED TO BC-29 CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/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+00 T/YR
OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49 LB/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 HOPPER CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/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+00 T/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, % 17.4 1.73E-04 LB/T 2000T/HR 4.20E-02 3.45E-01 ENCLOSURE 88 5.05E-03 4.15E-02 OR BC-43A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.87E+05 T/YR FOAM 3RD CARRYOVER
BC-43 FEED TO BC-45 OR CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR 6.99E-02 6.56E-01 ENCLOSURE 70 2.10E-02 1.97E-01 TO BC-43A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR
BC-44 FEED TO CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 1000T/HR 4.11E-02 3.28E-01 ENCLOSURE 70 1.23E-02 9.83E-02 BC-32 OR BC-45 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.51E+05 T/YR
**EMISSIONS SUB-TOTAL 1.53E-01**  **1.33E+00 3.83E-02**  **3.36E-01**

26 TRANSFER STATN H BC-54 AND BC-32 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 4000T/HR **4.80E-02 6.91E-01**  ENCLOSURE 97 **1.44E-03 2.07E-02**  BC-33, BC-35 OR BC-47 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/YR FOAM SUPPRESSION 27 COAL STORAGE BC-33 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.10E-02 3.45E-01 ENCLOSURE 94 1.26E-03 2.07E-02

SILOS 5 & 6 STORAGE SILO #5 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.43E+05 T/YR FOAM 1ST CARRYOVER BC-33 FEED TO BC-34 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.10E-02 3.45E-01 ENCLOSURE 94 1.26E-03 2.07E-02 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.43E+05 T/YR FOAM 1ST CARRYOVER BC-34 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.10E-02 3.45E-01 ENCLOSURE 91 1.89E-03 3.11E-02 STORAGE SILO #6 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.43E+05 T/YR FOAM 2nd CARRYOVER SILOS FEED TO BC-35 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 4.20E-02 3.45E-01 ENCLOSURE 88 5.05E-03 4.15E-02 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.87E+05 T/YR FOAM 3RD (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 4.87E+05 FOAM 3RD CARRYOVER **EMISSIONS SUB-TOTAL 1.05E-01**  **1.38E+00 9.46E-03**  **1.14E-01**

28 TRANSFER STATN J BC-35 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 4.20E-02 3.45E-01 ENCLOSURE 85 6.31E-03 5.18E-02 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.87E+05 T/YR FOAM 4TH BC-36 AND BC-37 CARRYOVER BC-46 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.95E-03 3.45E-01 ENCLOSURE 70 1.79E-03 1.04E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.89E+04 T/YR BC-36 AND BC-37 **EMISSIONS SUB-TOTAL 4.80E-02**  **6.91E-01 8.09E-03**  **1.55E-01**

29 TRANSFER STATN K BC-36 AND BC-37 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 4.80E-02 3.45E-01 ENCLOSURE 70 1.44E-02 1.04E-01 FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/YR BC-38, BC-39 AND SCREENS BC-38 AND BC-39 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 4.80E-02 1.73E-01 ENCLOSURE 70 1.44E-02 5.18E-02 FEED TO SCREENS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/YR (WASH PLANT) **EMISSIONS SUB-TOTAL 9.60E-02**  **5.18E-01 2.88E-02**  **1.55E-01**

30 TRANSFER STATN L BC-41 FEED TO CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR 6.99E-02 6.56E-01 ENCLOSURE 70 2.10E-02 1.97E-01 SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR
SURGE HOPPER CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR 6.99E-02 6.56E-01 ENCLOSURE 70 2.10E-02 1.97E-01 FEED TO BC-42 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR
SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 1.545T/HR 8.24E-03 7.73E-02 ENCLOSURE 70 2.47E-03 2.32E-02 BC-41 SAMPLER (AP-42, SEC. 8.23) 3.30E+02 T/YR
**EMISSIONS SUB-TOTAL 1.48E-01**  **1.39E+00 4.44E-02**  **4.17E-01**

31 TRANSFER STATN M BC-42 FEED TO BC-43 CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR **6.99E-02 6.56E-01**  ENCLOSURE 70 **2.10E-02 1.97E-01**  (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/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 EMISSION FACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 32 BARGE UNLOADER/ BARGE UNLOADER CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 4000T/HR 2.71E-01 6.91E-01 WATER SPRAY 80 5.43E-02 1.38E-01

SURGE HOPPER DUMP TO BC-49 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR
BC-49 DUMP TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 4000T/HR 2.71E-01 6.91E-01 ENCLOSURE 70 8.14E-02 2.07E-01 SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR

HOPPER DUMP TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.71E-01 3.45E-01 ENCLOSURE 70 8.14E-02 1.04E-01 BC-50 AND BC-51 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR

**EMISSIONS SUB-TOTAL 8.14E-01**  **1.73E+00 2.17E-01**  **4.49E-01**

33 TRANSFER STATION N BC-50 & BC-51 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.71E-01 3.45E-01 ENCLOSURE 97 8.14E-03 1.04E-02

(BREAKERS NO. 4-7) BREAKERS 4-7 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR FOAM SUPPRESSION BREAKERS 4-7 PRIMARY CRUSHER

--- --- 0.02LB/T 2000T/HR 3.14E+01 4.00E+01 ENCLOSURE 97 9.43E-01 1.20E+00 (AP-42, SEC. 8.23) 3.14E+06 T/YR FOAM SUPPRESSION BREAKERS FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.71E-01 3.45E-01 ENCLOSURE 94 1.63E-02 2.07E-02 TO BC-52 & BC-53 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR FOAM 1ST CARRYOVER BREAKERS FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 100T/HR 8.64E-05 1.73E-02 ENCLOSURE 94 5.18E-06 1.04E-03 REFUSE CONVEYORS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03 T/YR FOAM 1ST CARRYOVER SAMPLE CRUSHER SECONDRY CRUSHER

--- --- 0.05LB/T 4.219T/HR 1.66E-01 2.11E-01 ENCLOSURE 70 4.97E-02 6.33E-02 BC-50 & BC-51 SAMPLER (AP-42, SEC. 8.23) 6.63E+03 T/YR
REFUSE CONVEYORS CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 100T/HR 8.64E-05 1.73E-02 PART ENCL. 85 1.30E-05 2.59E-03 FEED TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.00E+03 T/YR FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 3.21E+01**  **4.09E+01 1.02E+00**  **1.30E+00**

34 TRANSFER STATN P BC-52 AND BC-53 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.71E-01 3.45E-01 ENCLOSURE 91 2.44E-02 3.11E-02

& STORAGE BYPASS FEED TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.14E+06 T/YR FOAM 2ND BC-54 OR BC-55 CARRYOVER
BC-55 FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 1.05E-01 3.45E-01 ENCLOSURE 97 3.15E-03 1.04E-02 TO BC-55A (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.22E+06 T/YR FOAM (STORAGE BYPASS CONV.) SUPPRESSION
BC-55A FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 1.05E-01 3.45E-01 ENCLOSURE 94 6.30E-03 2.07E-02 BC-18 (RECLAIM CONV.) (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.22E+06 T/YR FOAM 1ST CARRYOVER **EMISSIONS SUB-TOTAL 4.82E-01**  **1.04E+00 3.39E-02**  **6.22E-02**

35 LONG-TERM OPEN STORAGE WIND EROSION OF SILT CONTENT, % 4 2.49 LB/ACRE-D 35 ACRE 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, % 17.4 1.73E-04 LB/T 2000T/HR 1.34E-01 3.45E-01 PARTIAL 50 6.71E-02 1.73E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.55E+06 T/YR ENCLOSURE PAN SCRAPERS BC-55 STOCKOUT BATCH DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 7.54E-02 3.45E-01 PARTIAL 95 3.77E-03 1.73E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 8.73E+05 T/YR ENCLOSURE PAN SCRAPERS FOAM SUPPRESSION BC-47 STOCKOUT BATCH DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 0.00E+00 3.45E-01 PARTIAL 90 0.00E+00 3.45E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00 T/YR ENCLOSURE PAN SCRAPERS FOAM 1ST CARRYOVER PAN SCRAPERS UNPAVED ROAD SILT CONTENT, % 4 7.60 LB/VMT 2000T/HR 1.90E+01 2.77E+01 WET 75 4.74E+00 6.92E+00 STOCKOUT HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 2.74E+06 T/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 5.28 LB/VMT 2000T/HR 1.32E+01 1.92E+01 WET 75 3.29E+00 4.80E+00 STOCKOUT HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 2.74E+06 T/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, % 17.4 1.73E-04 LB/T 2000T/HR 2.37E-01 3.45E-01 NONE 0 2.37E-01 3.45E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.74E+06 T/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 EMISSION FACTOR (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 1.48E+01 2.77E+01 WET 75 3.71E+00 6.92E+00 (CONT'D) COAL STORAGE YARD RECLAIM HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 2.14E+06 T/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 5.28 LB/VMT 2000T/HR 1.03E+01 1.92E+01 WET 75 2.57E+00 4.80E+00 RECLAIM HAULING, FUGITIVE DUST VEHICLE SPEED, MPH 15 2.14E+06 T/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, % 17.4 1.73E-04 LB/T 2000T/HR 1.79E-01 3.45E-01 NONE 0 1.79E-01 3.45E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.07E+06 T/YR RECLAIM HOPPER BC-18 RECLAIM HOPPER BATCH DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 1.79E-01 3.45E-01 ENCLOSURE 97 5.37E-03 1.04E-02 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.07E+06 T/YR FOAM BC-18 SUPPRESSION
STORAGE PILE UNPAVED ROAD SILT CONTENT, % 4 0.45 LB/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+02 VMT/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, % 17.4 1.73E-04 LB/T 2000T/HR 5.95E-03 3.45E-01 NONE 0 5.95E-03 3.45E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.89E+04 T/YR RECLAIM HOPPER BC-46 RECLAIM HOPPER BATCH DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.95E-03 3.45E-01 ENCLOSURE 70 1.79E-03 1.04E-01 DISCHG COAL TO (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.89E+04 T/YR BC-46
PILE WATERING UNPAVED ROAD SILT CONTENT, % 4 1.65 LB/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 8.27E+01**  **1.09E+02 3.31E+01**  **3.14E+01**

36 COVERED LIVE BC-9 FEED TO SILO # 1 OR CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 70 1.64E-01 1.04E-01

STORAGE SILOS BC-10 FEED TO SILO #2 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR (SILOS #1 and #2) BC-9 TO BC-10 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 2.74E-01 3.45E-01 ENCLOSURE 70 8.21E-02 1.04E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.17E+06 T/YR
SILO #1or #2 TO BC-11 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 70 1.64E-01 1.04E-01 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR
**EMISSIONS SUB-TOTAL 1.37E+00**  **1.04E+00 4.11E-01**  **3.11E-01**

37 CONDITIONERS BC-11 OR BC-12 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 97 1.64E-02 1.04E-02

(CRUSHERS) TO SURGE HOPPER (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR FOAM SUPPRESSION SURGE HOPPER TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 94 3.28E-02 2.07E-02 CONDITIONERS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR FOAM 1ST CARRYOVER CONDITIONERS SECONDARY CRUSHER

--- --- 0.05LB/T 2000T/HR 1.58E+02 1.00E+02 ENCLOSURE 94 9.51E+00 6.00E+00 (4 WITH ONE SPARE) AP-42 SEC. 8.23 6.34E+06 T/YR FOAM 1ST CARRYOVER CONDITIONERS FEED CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 91 4.93E-02 3.11E-02 TO BC-13 AND BC-14 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR FOAM 2ND CARRYOVER **EMISSIONS SUB-TOTAL 1.60E+02**  **1.01E+02 9.61E+00**  **6.06E+00**

38 POWERHOUSE BC-13 AND BC-14 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 2000T/HR 5.47E-01 3.45E-01 ENCLOSURE 88 6.57E-02 4.15E-02

TRANSFER STATIONS BC-15, BC-17, OR BC-22 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 6.34E+06 T/YR FOAM 3RD CARRYOVER BC-15 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.74E-01 1.73E-01 ENCLOSURE 85 4.11E-02 2.59E-02 BC-16 OR BC-23 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.17E+06 T/YR FOAM 4TH CARRYOVER BC-23 OR BC-24 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.11E-01 1.73E-01 ENCLOSURE 70 3.33E-02 5.18E-02 BC-25 OR BC-27 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.28E+06 T/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 EMISSION FACTOR (PROCESS MEASURE) T/YR LB/HR CONTROLS EFFICIENCY(3) T/YR LB/HR 38 POWERHOUSE BC-25 TO BC-26 CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 2.22E-02 1.73E-01 ENCLOSURE 70 6.66E-03 5.18E-02 (CONT'D) TRANSFER STATIONS (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 2.57E+05 T/YR
BC-22 FEED TO CONT. DROP H2O CONTENT, % 17.4 1.73E-04 LB/T 1000T/HR 1.11E-01 1.73E-01 ENCLOSURE 85 1.66E-02 2.59E-02 BC-24 OR BC-26 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 1.28E+06 T/YR FOAM 4TH CARRYOVER **EMISSIONS SUB-TOTAL 1.07E+00**  **1.04E+00 1.63E-01**  **1.97E-01**

39 COAL WASH PLANT FEED FROM HOPPERS CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR 6.99E-02 6.56E-01 ENCLOSURE 70 2.10E-02 1.97E-01

(CLEAN COAL) T0 BC-40 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR

BC-40 FEED CONT. DROP H2O CONTENT, % 11 3.28E-04 LB/T 2000T/HR 6.99E-02 6.56E-01 ENCLOSURE 70 2.10E-02 1.97E-01 TO BC-41 (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 4.27E+05 T/YR
MAGNETITE FEED FROM CONT. DROP H2O CONTENT, % 2 3.57E-03 LB/T 25T/HR 1.43E-02 8.91E-02 ENCLOSURE 70 4.28E-03 2.67E-02 DELIVERY TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 8.00E+03 T/YR
REFUSE FEED FROM WASH CONT. DROP H2O CONTENT, % 10 3.75E-04 LB/T 400T/HR 1.04E-01 1.50E-01 ENCLOSURE 70 3.12E-02 4.50E-02 PLANT TO REFUSE CONV. (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/YR
**EMISSIONS SUB-TOTAL 2.58E-01**  **1.55E+00 7.75E-02**  **4.65E-01**

40 COAL WASH PLANT REFUSE CONVEYOR FEED TO BATCH DROP H2O CONTENT, % 10 3.75E-04 LB/T 400T/HR 1.04E-01 1.50E-01 PARTIAL 50 5.21E-02 7.49E-02

COARSE REFUSE DUMP TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/YR ENCLOSURE DISPOSAL DUMP TRUCK UNPAVED ROAD SILT CONTENT, % 9.6 16.78 LB/VMT 400T/HR 7.00E+01 1.01E+02 WET 95 3.50E+00 5.04E+00

REFUSE HAULING ON FUGITIVE DUST VEHICLE SPEED, MPH 15 5.56E+05 T/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 5.56E+05 T/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-04 LB/T 400T/HR 1.04E-01 1.50E-01 NONE 0 1.04E-01 1.50E-01 DISCHARGE TO PILE (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 5.56E+05 T/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+03 VMT/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 40 ACRE 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 5.56E+05 T/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 3.76E+01 1.02E-02 WET 95 1.88E+00 5.12E-04 REFUSE HAULING ON FUGITIVE DUST VEHICLE SPEED, MPH 15 5.56E+05 T/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 1.08E+02**  **1.01E+02 5.53E+00**  **5.26E+00**

**CY05 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 5.54E+03 1.16E+04 3.13E+02 7.13E+02

------------ ------------ ------------ ------------
**5.54E+03 1.16E+04**  **3.13E+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 EMISSION FACTOR (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. 07/12/06

Page 7 of 7Lstone


### 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 EMISSION FACTOR (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 2.48E+02 1.18E+03 WET 95 1.24E+01 5.90E+01

TRUCK UNLOADING HAULING ONE-WAY EMPTY FUGITIVE DUST VEHICLE SPEED, MPH 20 3.79E+05 T/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 4.94E+02 2.35E+03 WET 95 2.47E+01 1.17E+02 HAULING ONE-WAY FULL FUGITIVE DUST VEHICLE SPEED, MPH 20 3.79E+05 T/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 3.66E-01 1.74E+00 NONE 0 3.66E-01 1.74E+00 RAILCAR/TRUCK (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.79E+05 T/YR TO HOPPER

**EMISSIONS SUB-TOTAL 7.42E+02**  **3.53E+03 3.75E+01**  **1.78E+02**

42 RECLAIM/RECEIVING BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 3600 SCF/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 1 COLLECTR 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 2000 SCF/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 1 COLLECTR 8760HR/YR

46-48 LIMESTONE STORAGE BAGFILTER

--- MANUFACTURER'S

--- 2.00E-02 GR/SCF 4000 SCF/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 3.66E-01 1.39E+00 ENCLOSURE 70 1.10E-01 4.17E-01 CONVEYORS N-306-A,-B, & -C (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.79E+05 T/YR

Page 1 of 2 CONVEYORS N-306-A,-B, & -C (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 3.79E+05 T/YR TO SURGE HOPPERS

52 LIMESTONE HANDLING DISCHARGE TO STORAGE CONT. DROP H2O CONTENT, % 3.1 1.93E-03 LB/T 900T/HR 0.00E+00 1.74E+00 TELESCOPING 50 0.00E+00 8.69E-01

BULK STORAGE PILE PILE FROM CONVEYOR (AP-42 SEC. 11.2.3-3) AVG WIND SPEED, MPH 6.85 0.00E+00 T/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 3.03E+00**  **4.08E+00 3.03E+00**  **3.21E+00**

53-54 LIME STORAGE SILO BAGFILTER

--- ENG. ESTIMATE

--- 2.00E-02 GR/SCF 1150 SCF/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 3.76E+00 7.21E+00 3.51E+00 5.37E+00 OFF-PERMIT FUGITIVES 7.42E+02 3.53E+03 3.71E+01 1.76E+02 FUGITIVE TOTAL 7.46E+02 3.53E+03 4.06E+01 1.82E+02

------------ ------------ ------------ ------------ ON-PERMIT TOTAL **1.88E+03 4.75E+02**  **2.23E+01 1.00E+01**  Page 1 of 2Lstone



### 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). 07/12/06

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

**CY05 PAF By-Product Handling Fugitive-Dust Emission Estimates CY05 PAF By-Product (Ash/Gypsum) Production/Utilization Estimates** **

Production, tons/yr (tpy) Notes Fly Ash (U1-2) = 85,479 Fly Ash (U3) = 40,193 Fly Ash Total = 125,672 Bottom Ash/Slag = 377,016 Gypsum (U1-2) = 508,926 Production Subtotal = 1,011,614

Utilization, tpy Fly Ash = 0 Bottom Ash/Slag = 337,203Off-Site Processing for Roofing Granules, Blasting Grit 0On-Site for Road Construction and Repair Bottom Ash/Slag Total = 337,203 Gypsum = 113,523On-Site Cover material for coal wash refuse 3,158Off-Site Agricultural Soil Amendment 0 0 Gypsum Total = 116,681 Utilization Subtotal = 453,884 **Reference: Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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: CY05 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. **CY05 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 = 5.07E+00 PAF Bottom Ash/Slag Byproduct Sales = 9.52E+00 PAF Fly Ash Byproduct Disposal = Negligible CY05 PAF By-Product Handling PM Emission Total = 1.46E+01 For sources subject to TRI reporting. **CY05 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)

- 7.34E-05 3.26E-05

- 1.06E-04 Arsenic (As)

- 3.44E-04 8.48E-05

- 4.29E-04 Barium (Ba)

- 1.49E-03 7.60E-03

- 9.10E-03 Beryllium (Be)

- 4.45E-05 2.94E-05

- 7.39E-05 Cadmium (Cd)

- 2.62E-05 2.55E-05

- 5.17E-05 Chromium (Cr)

- 3.04E-04 8.72E-04

- 1.18E-03 Cobalt (Co)

- 2.18E-04 5.50E-04

- 7.68E-04 Copper (Cu)

- 2.88E-04 3.74E-04

- 6.62E-04 Lead (Pb)

- 5.50E-04 1.71E-04

- 7.21E-04 Manganese (Mn)

- 4.28E-04 3.26E-03

- 3.69E-03 Mercury (Hg)

- 1.02E-06 3.01E-06

- 4.03E-06 Molybdenum (Mo)

- 2.76E-04 4.04E-04

- 6.81E-04 Nickel (Ni)

- 3.00E-04 7.71E-04

- 1.07E-03 Selenium (Se)

- 4.89E-05 7.56E-05

- 1.24E-04 Silver (Ag)

- 1.60E-06 1.41E-05

- 1.57E-05 Thallium (Tl)

- 5.91E-05 5.79E-05

- 1.17E-04 Vanadium (V)

- 9.33E-04 3.65E-03

- 4.58E-03

Page 3 of 4

# ash

Zinc (Zn)

- 1.39E-03 1.04E-03

- 2.43E-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)

- 7.53E-09

- 7.53E-09 Benzo(a)phenanthrene (218-01-9)

- 7.14E-08

- 7.14E-08 Benzo(a)pyrene (50-32-8)

- 1.63E-08

- 1.63E-08 Benzo(b)fluoranthene (205-99-2)

- 1.88E-07

- 1.88E-07 Benzo(k)fluoranthene (207-08-9)

- 2.07E-07

- 2.07E-07 Dibenz(a,h)anthracene (53-70-3)

- 7.30E-09

- 7.30E-09 Fluoranthene (206-44-0)

- 3.23E-08

- 3.23E-08 Indeno(1,2,3-cd)-pyrene (193-39-5)

- 8.81E-09

- 8.81E-09
Other EPCRA PAH Anthracene (120-12-7)

- 6.53E-09

- 6.53E-09 Benzo(g,h,i)perylene (191-24-2)

- 1.40E-08

- 1.40E-08 Naphthalene (91-20-3)

- 1.71E-07

- 1.71E-07 Phenanthrene (85-01-8)

- 1.05E-07

- 1.05E-07 TVA Air, Land & Water Sciences 07/12/06

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 PAF Unit 3 Total coal burn (tons/yr):(4) 

### 1,866,460 2,127,618 3,994,078 2,569,468 Total boiler use (hr/yr):(4) 

### 7,397 8,452 15,848 5,705 **Flue gas flow by CEMS or by amount of coal burned**(2) 

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

### 3,185 3,811 6,996 3,072 CY05 SCR operating factor (w/ NH3 feed): 0.431 0.451 0.441 0.538 Coal burn (tons/ozone season) ILB 1,741,886 Coal burn during SCR NH3 feed (tons/yr): 803,715 959,356 1,763,070 1,383,648 PRB 21,184
Coal heating value (Btu/lb)(3) 

### ILB 11500 Region PAF Unit 1 PAF Unit 2 PAF Units 1-2 PAF Unit 3 PRB 8775 ILB 1,847,875 2,098,385 3,946,260 745,146 PRB 18,585 29,233 47,818 1,824,322 **NOx Reduction Ammonia Slip** Dry Basis Total 1,866,460 2,127,618 3,994,078 2,569,468 Average ammonia slip (ppmv wet basis)(6) 

### 1.8383 2ppmvd(6)

### at 3% O2.
Operating factor for SCR/SNCR (fraction)(7) 

### 1 Region PAF Unit 1 PAF Unit 2 PAF Units 1-2 PAF Unit 3 ILB 795,712 946,174 1,741,886 401,258 **FGC Ammonia Injection** PRB 8,003 13,181 21,184 982,390 Total 803,715 959,356 1,763,070 1,383,648
**Fly Ash Sales Factor (decimal fraction) (8)**  

### 0 NH3 rcvd lbs 988,000(truck) Truck-unloading NH3 emission factor = 1.38E-05lb/lb of recpts **Fugitive losses from tank farm (9)**  

### 15.6 18,800,924(rail) Railcar-unloading NH3 emission factor = 1.05E-07lb/lb of recpts
**Ammonia in boiler water treatment (lbs) (10)**  

### 10,374 44,460lbs of aqua ammonia, assumed to be 35% ammonia Boiler water discharge (open tank or ash pond) Ash Pond

Notes: (1)

### Ammonia RY

2005 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 "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey (PAF Units 1-2) & Excel file "CY 2005 TRI Coal Data_020306.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. (PAF Unit 3). (4)

### Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in FPG Env Affr - TRI folder on "Chapgfs5" server. (5)

### SCR hours with ammonia feed provided in the TRI CY05 Fossil Questionnaire and archived in CY 05\Completed Questionnaires\PAF folder. (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 CY05 PAF fly-ash sales, per Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson et al., archived in the CY 05\Release Estimates\Ash Data folder. (9)

### Anhydrous ammonia receipts/usage listed in 3-13-06 e-mail from K.J. Dukes to M.F. Broder et al., archived in CY 05\Completed Questionnaire\PAF folder. Fugitives from tank farm are included in only the first model run for PAF Units 1 and 2. (10)

### Aqua NH3 usage listed in 3-13-06 e-mail from K.J. Dukes to M.F. Broder et al., archived in CY05\Completed Questionnaire\PAF folder. Unless otherwise indicated, BWT NH3 usage estimated at aqua NH3 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 PRB Total Contrl Effcncy, % PAF 1 PAF 2 NH3 SCR-exit 40,420 375 40,795 NH3 Stack 0.40 2.81 3.22 99.99 1.47 1.75 Ammonium salts(1) 

### Stack 1,139 2.82 1,142 NH3 Fugitive 7,292 335 7,627

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 07/12/06 **Table 1. Input Data for CY05 PAF Units 1-2 Ammonia (NH3) Emission-Estimation Model (1)** 



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

Coal Region **Table 2. Summary of CY05 PAF Units 1-2 Ammonia (NH3) & Ammonium-Salt Air Emission Estimates** CY05 PAF Units 1-3 Coal Burn & Boiler/SCR Operating Data:

CY05 PAF Units 1-3 Coal Burn by Supply Region, tons/yr(3)



### CY05 PAF Units 1-3 Coal burned by region during NH3 feed, tons/yr

Page 1 of 1

# H2SO4

**CY05 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 0.3% for Powder River Basin (PRB) subbituminous coal. The PAF boilers are cyclone-fired. In CY05, PAF Units 1-2 burned nearly 100% Illinois Basin (ILB) Easten bituminous coal, but CY05 PAF Unit 3 heat inputs consisted of 34.9% ILB coal & 65.1 % 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 in a 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 CY05; the system was inactive.(3)


# Table 1. CY05 PAF Flue-Gas-Conditioning (FGC) SO3/H2SO4 Manufacture Estimates CY05 PAF molten-S receipts 0pounds Molten-S tank capacity = 50tons CY05 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 CY05 PAF SO3/H2SO4 emissions. **Table 2. CY05 PAF Coal-fired Region-Specific Boiler Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**
COAL REGION: IL Basin Bituminous BOILER/COAL TYPE: CYCL/E. BITUM SO3/SO2 MOLAR RATIO (%): 1.6

Blr Unit: PAF 1 PAF 2 PAF 3 PAF 1-3 Coal Burned, tons/year 1,847,875 2,098,385 745,146 4,691,406 Coal Heating Value, As Received (Btu/lb) 11,500 11,500 11,500 Sulfur Content, % 2.69 2.69 2.69 Coal Sulfur Conversion to Sulfur Oxides (SOx), % 95 95 95 Coal-fired Heat Inputs, 10^12 Btu/yr 42.50 48.26 17.14 107.90 Boiler-Exit SOx expressed as SO2, tons/yr 94,349 107,139 38,046 239,534 Boiler-Exit SOx converted to SO3, % 1.60 1.60 1.60 Boiler SO3/H2SO4 Production, tons H2SO4/yr 2,311 2,624 932 5,867 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 1277 1450 610 3,337
COAL REGION: PRB Subbituminous BOILER/COAL TYPE: CYCL/PRB SO3/SO2 MOLAR RATIO (%): 0.3

Blr Unit: PAF 1 PAF 2 PAF 3 PAF 1-3 Coal Burned, tons/year 18,585 29,233 1,824,322 1,872,140 Coal Heating Value, As Received (Btu/lb) 8,775 8,775 8,775 Sulfur Content, % 0.35 0.35 0.35 Coal Sulfur Conversion to Sulfur Oxides (SOx), % 87.5 87.5 87.5 Coal-fired Heat Inputs, 10^12 Btu/yr 0.33 0.51 32.02 32.86 Boiler-Exit SOx expressed as SO2, tons/yr 114 179 11,163 Boiler-Exit SOx converted to SO3, % 0.300 0.300 0.300 Boiler SO3/H2SO4 Production, tons H2SO4/yr 0.522 0.822 51.3 52.6 Air Pollution Control System(s): AH/W+WV AH/W+WV AH/W+ESP Overall SO3/H2SO4 Control Efficiency, % 41.5 41.5 55.0 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 0.306 0.481 23.1 23.9

Page 1 of 4

# H2SO4

**Table 3. CY05 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 PAF 1-3 Coal-Total Heat Inputs, 10^12 Btu/yr 42.83 48.78 91.60 49.16 140.76 Boiler-Exit SOx expressed as SO2, tons/yr 94,463 107,318 201,781 49,208 250,989 Boiler SO3/H2SO4 Production, tons H2SO4/yr 2,312 2,625 4,937 983 5,920 Boiler contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 1277 1450 2,728 633 3,361 SO3/H2SO4 Control Efficiency, % 44.7 44.7 44.7 35.6 43.2 Blr contrib. to SO3/H2SO4 stk concen (ppmvd at 3% O2) 20.6 20.5 20.5 8.9 16.5

**Production & Emission Estimates for SO3/H2SO4 Derived from PAF Selective-Cataly tic-Reduction (SCR) Reactors**  Ammonia (NH3)-based selective-catalytic-reduction (SCR) reactors for nitrogen oxides (NOx) control have been installed on PAF Units 1-3 since CY00. 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. Total CY05 SCR in-service hours (with & without NH3 inputs)(5)

# were used to estimate annual emissions. 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, 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. 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. CY05 PAF Coal-fired Region-Specific SCR-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**
COAL REGION: IL Basin Bituminous Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 PAF 1-3 Boiler-Exit SOx expressed as SO2, tons/yr 94,349 107,139 201,488 38,046 239,534 SCR total (w/ & w/o NH3) in-service hours 3,586 4,133 3,400 Boiler in-service hours 7,397 8,452 5,705 SCR operation factor (total) 0.485 0.489 0.596 SCR SO3/H2SO4 production, tons H2SO4/yr 525 602 1,127 260 1,387 Air Pollution Control System(s): AH/HSE+WV AH/HSE+WV AH/HSE+ESP Overall SO3/H2SO4 Control Efficiency, % 44.8 44.8 34.6 SCR-outlet NH3 Slip (ppmvd at 3% O2) 2 2 2 SCR in-service hours (with NH3) 3,185 3,811 3,072 SCR operation factor (with NH3) 0.431 0.451 0.538 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 261 297 558 153 711
COAL REGION: PRB Subbituminous Blr Unit: PAF 1 PAF 2 PAF 1-2 PAF 3 PAF 1-3 Boiler-Exit SOx expressed as SO2, tons/yr 114 179 293 11,163 11,455 SCR total (w/ & w/o NH3) in-service hours 3,586 4,133 3,400 Boiler in-service hours 7,397 8,452 5,705 SCR operation factor (total) 0.485 0.489 0.596 SCR SO3/H2SO4 production, tons H2SO4/yr 0.633 1.00 1.64 76.4 78.0 Air Pollution Control System(s): AH/W+WV AH/W+WV AH/W+ESP Overall SO3/H2SO4 Control Efficiency, % 41.5 41.5 55.0 SCR-outlet NH3 Slip (ppmvd at 3% O2) 2 2 2 SCR in-service hours (with NH3) 3,185 3,811 3,072 SCR operation factor (with NH3) 0.431 0.451 0.538 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 0.132 0.194 0.326 11.8 12.2

**Table 5. CY05 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 PAF 1-3 Coal-Total Heat Inputs, 10^12 Btu/yr 42.83 48.78 91.60 49.16 140.76 Total-Coal SCR SO3/H2SO4 Production, tons H2SO4/yr 526 603 1,128 337 1,465 SCR contributn to SO3/H2SO4 stack emssn, tons H2SO4/yr 261 298 559 165 723 SO3/H2SO4 Control Efficiency, % 50.4 50.6 50.5 51.1 50.6 SCR contrib. to SO3/H2SO4 stk concen (ppmvd at 3% O2) 4.2 4.2 4.2 2.3 3.5

Page 2 of 4

# H2SO4

**Production & Emission Estimates for SO3/H2SO4 Derived from PAF Unit 3 Flue-Gas Conditioning (FGC) Sy stem**  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. CY05 PAF Flue-Gas-Conditioning (FGC) SO3/H2SO4 Manufacture/Emission Estimates (HSD Method)**
CY05 Parameters: PAF 3 Coal Region IL Basin PRB All Coals Coal Burn, ton/yr (as received) 745,146 1,824,322 2,569,468 Heat Value, Btu/lb (as received) 11,500 8,775 FGC System Operating Factor, % 0.00 0.00 Based on CY05 S receipts. SO3 Injection Rate, ppmv at 6% O2 10 10 FGC SO3/H2SO4 production, tons H2SO4/yr 0 0 0 SO3/H2SO4 release due to FGC operatn, tons/yr 0.0 0.0 0.0 **Table 7. CY05 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 PAF3 PAF 1-3 SO3/H2SO4 Production Rate, tons H2SO4/yr 2,837 3,228 6,065 1,320 7,385 AH-inlet SO3/H2SO4 Concentration (ppmvd at 3% O2) 45.7 45.6 45.7 18.5 36.2

**Table 8. CY05 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 PAF3 PAF 1-3 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 1,538 1,748 3,286 798 4,084 Overall SO3/H2SO4 Control Efficiency, % 45.8 45.8 45.8 39.6 44.7 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 24.8 24.7 24.7 11.2 20.0
A test campaign(9)

# was conducted on PAF Unit 2 in March 2005 to evaluate opacity-reduction measures such as hydrated-lime injection. Stack-exit SO3/H2SO4 flue-gas measurements averaged 17.7ppmvd at 3% O2 under baseline conditions (burning 100% ILB coal, with in-service SCR reactors but no lime injection). Stack-exit SO3/H2SO4 flue-gas measurements burning ILB coal with sulfur content typical of CY05 coal burn, but with the 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 CY05 PAF Units 1-2 emissions, and has decided to use the test data for those units' TRI and emission-fee inventory estimates. CY05 PAF Units 1-2 SO3/H2SO4 emissions were estimated in Table 9 based on annual-average stack-exit flue-gas concentrations, as apportioned from the test data according to each unit's CY05 SCR operation factor. HSD emission estimates were deemed appropriate for PAF Unit 3, with its high fraction of low-sulfur PRB coal burn. 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 annual-average flue-gas concentrations, and will use those values to estimate PAF boiler and SCR-reactor SO3/H2SO4 manufacture and treatment quantities for TRI reporting. **Table 9. CY05 PAF Coal-fired SO3/H2SO4 Emission Estimates (Final Values)**
Stack-Exit SO3/H2SO4 Flue-Gas Concentrations & Emission Rates Blr Unit: PAF1 PAF2 PAF 1-2 PAF3 PAF 1-3 Stack-exit SO3/H2SO4 Concentration (ppmvd at 3% O2) 15.9 15.9 15.9 11.2 14.3 SO3/H2SO4 Stack Emissions, tons H2SO4/yr 988 1126 2,114 798 2,912 Overall SO3/H2SO4 Control Efficiency, % 65.2 65.1 65.1 39.6 60.6

Page 3 of 4

# H2SO4

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)").

(2)

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

(3)

# Per 1-10-06 e-mail from J.E. Perkins to C.M. Anderson, no sulfur burn occurred at PAF in CY05.

(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 & w/o ammonia feed listed in PAF TRI CY05 Fossil Questionnaire, archived in CY 05\Completed Questionnaires\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).
TVA Environmental Technologies 07/12/06

Page 4 of 4

## 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 07/12/06

Page 1 of 1air

PARADISE FOSSIL PLANT BOILERS + FUGITIVE SOURCES CY05 AIR EMISSION ESTIMATES DATE: 07/12/06 (TONS/YEAR) BASED ON:

CY05 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 AVG OF CY01-CY05 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) 1525 0.137 1526 0.009 1684 0.0450 1684 865 0.180 865 4074 0.362 4075 0.01 313 59.4 22.3 394 4469 8.8 PM < 10-micrometer aero. diam. (PM10_fil) 1037 0.0758 1037 0.007 1145 0.0225 1145 588 0.0942 588 2770 0.192 2771 0.007 Not Not Not 2771 PM < 2.5-micrometer aero. diam. (PM2.5_fil) 549 0.0169 549 0.003 606 0.00562 606 311 0.0224 311 1467 0.0449 1467 0.003 Estimated Estimated Estimated 1467 Condensable PM (PM_cond) 428 0.0877 428 0.02 488 0.0292 488 2208 0.116 2208 3124 0.233 3124 0.007 3124 Sulfur dioxide (SO2) 13561 1.98 13563 0.01 17319 0.639 17320 53516 3.02 53519 84396 5.65 84402 0.007 84402 Nitrogen oxides (NOx) 11464 1.68 11466 0.01 14124 0.540 14125 10286 2.21 10289 35874 4.43 35879 0.01 35879 Carbon monoxide (CO) 467 0.378 467 0.08 532 0.112 532 642 0.488 643 1641 0.979 1642 0.06 1642 Volatile organic compds (VOC) 103 0.0217 103 0.02 117 0.00450 117 141 0.0261 141 361 0.0522 361 0.01 361 Sulfuric acid (SO3/H2SO4) as H2SO4(5) 988 0.0942 988 0.01 1126 0.0314 1126 798 0.125 798 2912 0.251 2912 0.01 2912 Ammonia (NH3)(6) 7.35E-04 7.35E-04 0.0 8.74E-04 8.74E-04 6.53 6.53 6.53 6.53 0.0 6.14 12.7 48.5

Trace-Element HAP Antimony (Sb) 2.48E-02 2.06E-04 2.50E-02 0.8 2.76E-02 6.85E-05 2.77E-02 9.22E-03 2.73E-04 9.49E-03 6.16E-02 5.47E-04 6.22E-02 0.9 1.07E-03 4.23E-05 1.06E-04 1.21E-03 6.34E-02 1.9 Arsenic (As) 3.86E-01 3.74E-05 3.86E-01 0.01 4.27E-01 1.25E-05 4.27E-01 1.17E-01 4.96E-05 1.17E-01 9.30E-01 9.94E-05 9.31E-01 0.01 2.29E-03 8.23E-05 4.29E-04 2.80E-03 9.33E-01 0.3 Beryllium (Be) 3.86E-02 2.80E-05 3.86E-02 0.07 4.23E-02 9.35E-06 4.23E-02 9.02E-03 3.72E-05 9.06E-03 8.99E-02 7.46E-05 9.00E-02 0.08 3.54E-04 8.82E-06 7.39E-05 4.37E-04 9.04E-02 0.5 Cadmium (Cd) 4.25E-02 2.88E-05 4.25E-02 0.07 4.75E-02 9.35E-06 4.76E-02 2.41E-02 3.79E-05 2.42E-02 1.14E-01 7.61E-05 1.14E-01 0.07 2.36E-04 1.71E-05 5.17E-05 3.05E-04 1.15E-01 0.3 Hydrogen chloride (HCl) 3.44E+01 2.90E-04 3.44E+01 0.001 3.90E+01 0.00E+00 3.90E+01 4.80E+02 8.35E-03 4.80E+02 5.53E+02 8.64E-03 5.53E+02 0.002 5.53E+02 Chromium (Cr) 3.28E-01 2.86E-05 3.28E-01 0.009 3.66E-01 9.35E-06 3.66E-01 1.78E-01 3.77E-05 1.78E-01 8.72E-01 7.56E-05 8.72E-01 0.009 4.03E-03 3.12E-04 1.18E-03 5.52E-03 8.77E-01 0.6 Cobalt (Co) 7.19E-02 8.51E-05 7.20E-02 0.1 8.01E-02 2.84E-05 8.01E-02 4.05E-02 1.13E-04 4.06E-02 1.92E-01 2.26E-04 1.93E-01 0.1 2.71E-03 2.94E-05 7.68E-04 3.50E-03 1.96E-01 1.8 Hydrogen fluoride (HF) 9.48E+00 0.00E+00 9.48E+00 0.0 1.08E+01 0.00E+00 1.08E+01 9.33E+01 0.00E+00 9.33E+01 1.14E+02 0.00E+00 1.14E+02 0.0 1.14E+02 Lead (Pb) 4.64E-01 8.71E-05 4.64E-01 0.02 5.14E-01 2.80E-05 5.14E-01 1.83E-01 1.14E-04 1.83E-01 1.16E+00 2.29E-04 1.16E+00 0.02 3.86E-03 9.41E-05 7.21E-04 4.68E-03 1.17E+00 0.4 Manganese (Mn) 5.06E-01 6.20E-05 5.06E-01 0.01 5.65E-01 1.87E-05 5.65E-01 3.24E-01 7.92E-05 3.24E-01 1.40E+00 1.60E-04 1.40E+00 0.01 9.16E-03 4.70E-03 3.69E-03 1.75E-02 1.41E+00 1.2 Mercury (Hg) 6.39E-02 2.80E-05 6.40E-02 0.04 7.25E-02 9.35E-06 7.25E-02 1.07E-01 3.72E-05 1.07E-01 2.44E-01 7.46E-05 2.44E-01 0.03 2.88E-05 5.00E-07 4.03E-06 3.33E-05 2.44E-01 0.0 Nickel (Ni) 3.31E-01 2.90E-05 3.31E-01 0.009 3.71E-01 9.35E-06 3.71E-01 1.77E-01 3.82E-05 1.78E-01 8.79E-01 7.65E-05 8.79E-01 0.009 3.85E-03 2.00E-04 1.07E-03 5.13E-03 8.84E-01 0.6 Selenium (Se) 3.31E-01 1.40E-04 3.31E-01 0.04 3.76E-01 4.67E-05 3.76E-01 6.41E-01 1.86E-04 6.41E-01 1.35E+00 3.73E-04 1.35E+00 0.03 5.04E-04 7.64E-05 1.24E-04 7.05E-04 1.35E+00 0.1

Organic HAP (CAS Number) 1,1-Dichloroethane (75343) 1.91E-02 1.91E-02 0.0 2.17E-02 2.17E-02 2.19E-02 2.19E-02 6.26E-02 6.26E-02 0.0 0.00E+00 6.26E-02 1,2-Dibromoethane (106934) 5.57E-02 5.57E-02 0.0 6.34E-02 6.34E-02 6.39E-02 6.39E-02 1.83E-01 1.83E-01 0.0 0.00E+00 1.83E-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) 3.21E-02 3.21E-02 0.0 3.66E-02 3.66E-02 3.69E-02 3.69E-02 1.06E-01 1.06E-01 0.0 0.00E+00 1.06E-01 1,3-Dichloropropene (542756) 1.54E-02 1.54E-02 0.0 1.76E-02 1.76E-02 1.77E-02 1.77E-02 5.07E-02 5.07E-02 0.0 0.00E+00 5.07E-02 1,4-Dichlorobenzene (106467) 2.36E-02 2.36E-02 0.0 2.68E-02 2.68E-02 2.70E-02 2.70E-02 7.74E-02 7.74E-02 0.0 0.00E+00 7.74E-02 2-Butanone (78933) 6.64E-02 0.00E+00 6.64E-02 0.0 7.56E-02 0.00E+00 7.56E-02 7.62E-02 0.00E+00 7.62E-02 2.18E-01 0.00E+00 2.18E-01 0.0 0.00E+00 2.18E-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) 4.28E-03 4.28E-03 0.0 4.88E-03 4.88E-03 4.92E-03 4.92E-03 1.41E-02 1.41E-02 0.0 0.00E+00 1.41E-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) 1.95E-01 1.95E-01 0.0 2.22E-01 2.22E-01 2.24E-01 2.24E-01 6.40E-01 6.40E-01 0.0 0.00E+00 6.40E-01 4-Methyl-2-pentanone (108101) 4.93E-02 4.93E-02 0.0 5.61E-02 5.61E-02 5.65E-02 5.65E-02 1.62E-01 1.62E-01 0.0 0.00E+00 1.62E-01 4-Methylphenol (106445) 2.36E-02 2.36E-02 0.0 2.68E-02 2.68E-02 2.70E-02 2.70E-02 7.74E-02 7.74E-02 0.0 0.00E+00 7.74E-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) 6.85E-02 0.00E+00 6.85E-02 0.0 7.80E-02 0.00E+00 7.80E-02 7.86E-02 0.00E+00 7.86E-02 2.25E-01 0.00E+00 2.25E-01 0.0 0.00E+00 2.25E-01 Acetophenone (98862) 2.57E-02 0.00E+00 2.57E-02 0.0 2.93E-02 0.00E+00 2.93E-02 2.95E-02 0.00E+00 2.95E-02 8.45E-02 0.00E+00 8.45E-02 0.0 0.00E+00 8.45E-02 Acrolein (107028) 4.07E-02 0.00E+00 4.07E-02 0.0 4.63E-02 0.00E+00 4.63E-02 4.67E-02 0.00E+00 4.67E-02 1.34E-01 0.00E+00 1.34E-01 0.0 0.00E+00 1.34E-01 Benzene (71432) 8.35E-02 0.00E+00 8.35E-02 0.0 9.51E-02 0.00E+00 9.51E-02 9.59E-02 0.00E+00 9.59E-02 2.74E-01 0.00E+00 2.74E-01 0.0 0.00E+00 2.74E-01 Benzyl chloride (100447) 6.00E-03 6.00E-03 0.0 6.83E-03 6.83E-03 6.88E-03 6.88E-03 1.97E-02 1.97E-02 0.0 0.00E+00 1.97E-02 Biphenyl (92524) 3.43E-03 3.43E-03 0.0 3.90E-03 3.90E-03 3.93E-03 3.93E-03 1.13E-02 1.13E-02 0.0 0.00E+00 1.13E-02 bis(2-Ethylhexyl)phthalate (117817) 7.71E-02 0.00E+00 7.71E-02 0.0 8.78E-02 0.00E+00 8.78E-02 8.85E-02 0.00E+00 8.85E-02 2.53E-01 0.00E+00 2.53E-01 0.0 1.72E-04 1.72E-04 2.54E-01 0.1 Bromomethane (74839) 1.91E-02 0.00E+00 1.91E-02 0.0 2.17E-02 0.00E+00 2.17E-02 2.19E-02 0.00E+00 2.19E-02 6.26E-02 0.00E+00 6.26E-02 0.0 0.00E+00 6.26E-02 Carbon disulfide (75150) 2.36E-02 2.36E-02 0.0 2.68E-02 2.68E-02 2.70E-02 2.70E-02 7.74E-02 7.74E-02 0.0 0.00E+00 7.74E-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) 3.43E-03 0.00E+00 3.43E-03 0.0 3.90E-03 0.00E+00 3.90E-03 3.93E-03 0.00E+00 3.93E-03 1.13E-02 0.00E+00 1.13E-02 0.0 0.00E+00 1.13E-02 Chloroethane (75003) 1.13E-02 1.13E-02 0.0 1.29E-02 1.29E-02 1.30E-02 1.30E-02 3.73E-02 3.73E-02 0.0 0.00E+00 3.73E-02 Chloroform (67663) 1.71E-02 0.00E+00 1.71E-02 0.0 1.95E-02 0.00E+00 1.95E-02 1.97E-02 0.00E+00 1.97E-02 5.63E-02 0.00E+00 5.63E-02 0.0 0.00E+00 5.63E-02 Chloromethane (74873) 2.36E-02 0.00E+00 2.36E-02 0.0 2.68E-02 0.00E+00 2.68E-02 2.70E-02 0.00E+00 2.70E-02 7.74E-02 0.00E+00 7.74E-02 0.0 0.00E+00 7.74E-02 Dibenzofuran (132649) 1.24E-02 1.24E-02 0.0 1.41E-02 1.41E-02 1.43E-02 1.43E-02 4.08E-02 4.08E-02 0.0 0.00E+00 4.08E-02 Dibutylphthalate (84742) 2.36E-03 2.36E-03 0.0 2.68E-03 2.68E-03 2.70E-03 2.70E-03 7.74E-03 7.74E-03 0.0 0.00E+00 7.74E-03 Dimethylphthalate (131113) 1.93E-03 1.93E-03 0.0 2.19E-03 2.19E-03 2.21E-03 2.21E-03 6.33E-03 6.33E-03 0.0 0.00E+00 6.33E-03 Ethyl benzene (100414) 1.71E-02 0.00E+00 1.71E-02 0.0 1.95E-02 0.00E+00 1.95E-02 1.97E-02 0.00E+00 1.97E-02 5.63E-02 0.00E+00 5.63E-02 0.0 0.00E+00 5.63E-02 Formaldehyde (50000) 5.57E-02 4.12E-03 5.98E-02 6.9 6.34E-02 1.37E-03 6.48E-02 6.39E-02 5.46E-03 6.94E-02 1.83E-01 1.09E-02 1.94E-01 5.6 0.00E+00 1.94E-01 n-Hexane (110543) 1.05E-02 1.05E-02 0.0 1.20E-02 1.20E-02 1.20E-02 1.20E-02 3.45E-02 3.45E-02 0.0 0.00E+00 3.45E-02 Hexachlorobenzene (118741) 8.78E-05 8.78E-05 0.0 1.00E-04 1.00E-04 1.01E-04 1.01E-04 2.89E-04 2.89E-04 0.0 0.00E+00 2.89E-04 Iodomethane (74884) 4.28E-02 4.28E-02 0.0 4.88E-02 4.88E-02 4.92E-02 4.92E-02 1.41E-01 1.41E-01 0.0 0.00E+00 1.41E-01 Isophorone (78591) 2.57E-02 2.57E-02 0.0 2.93E-02 2.93E-02 2.95E-02 2.95E-02 8.45E-02 8.45E-02 0.0 0.00E+00 8.45E-02 Methyl chloroform (71556) 1.31E-02 0.00E+00 1.31E-02 0.0 1.49E-02 0.00E+00 1.49E-02 1.50E-02 0.00E+00 1.50E-02 4.29E-02 0.00E+00 4.29E-02 0.0 0.00E+00 4.29E-02 Methyl methacrylate (80626) 2.36E-02 2.36E-02 0.0 2.68E-02 2.68E-02 2.70E-02 2.70E-02 7.74E-02 7.74E-02 0.0 0.00E+00 7.74E-02 Methylene chloride (75092) 7.71E-02 0.00E+00 7.71E-02 0.0 8.78E-02 0.00E+00 8.78E-02 8.85E-02 0.00E+00 8.85E-02 2.53E-01 0.00E+00 2.53E-01 0.0 0.00E+00 2.53E-01 Naphthalene (91203) 1.33E-02 0.00E+00 1.33E-02 0.0 1.51E-02 0.00E+00 1.51E-02 1.52E-02 0.00E+00 1.52E-02 4.36E-02 0.00E+00 4.36E-02 0.0 4.13E-04 1.71E-07 4.13E-04 4.40E-02 0.9 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) 7.07E-02 0.00E+00 7.07E-02 0.0 8.05E-02 0.00E+00 8.05E-02 8.11E-02 0.00E+00 8.11E-02 2.32E-01 0.00E+00 2.32E-01 0.0 3.10E-03 3.10E-03 2.35E-01 1.3 Polychlorinated biphenyl [PCB] (1336363) 3.21E-04 0.00E+00 3.21E-04 0.0 3.66E-04 0.00E+00 3.66E-04 3.69E-04 0.00E+00 3.69E-04 1.06E-03 0.00E+00 1.06E-03 0.00 0.00E+00 1.06E-03 Propionaldehyde (123386) 4.07E-02 0.00E+00 4.07E-02 0.0 4.63E-02 0.00E+00 4.63E-02 4.67E-02 0.00E+00 4.67E-02 1.34E-01 0.00E+00 1.34E-01 0.00 0.00E+00 1.34E-01 Styrene (100425) 1.50E-02 0.00E+00 1.50E-02 0.0 1.71E-02 0.00E+00 1.71E-02 1.72E-02 0.00E+00 1.72E-02 4.93E-02 0.00E+00 4.93E-02 0.00 0.00E+00 4.93E-02 Tetrachloroethylene (127184) 8.99E-03 0.00E+00 8.99E-03 0.0 1.02E-02 0.00E+00 1.02E-02 1.03E-02 0.00E+00 1.03E-02 2.96E-02 0.00E+00 2.96E-02 0.00 0.00E+00 2.96E-02 Toluene (108883) 3.64E-02 0.00E+00 3.64E-02 0.0 4.15E-02 0.00E+00 4.15E-02 4.18E-02 0.00E+00 4.18E-02 1.20E-01 0.00E+00 1.20E-01 0.00 0.00E+00 1.20E-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) 6.64E-03 6.64E-03 0.0 7.56E-03 7.56E-03 7.62E-03 7.62E-03 2.18E-02 2.18E-02 0.0 0.00E+00 2.18E-02 Vinyl chloride (75014) 1.56E-02 0.00E+00 1.56E-02 0.0 1.78E-02 0.00E+00 1.78E-02 1.79E-02 0.00E+00 1.79E-02 5.14E-02 0.00E+00 5.14E-02 0.0 0.00E+00 5.14E-02 Xylenes (1330207) 2.70E-02 0.00E+00 2.70E-02 0.0 3.07E-02 3.07E-02 3.10E-02 3.10E-02 8.87E-02 8.87E-02 0.0 0.00E+00 8.87E-02 Polycyclic organic matter (POM) 2.84E-02 2.23E-04 2.86E-02 0.8 3.23E-02 7.42E-05 3.24E-02 3.26E-02 2.95E-04 3.29E-02 9.32E-02 5.92E-04 9.38E-02 0.6 4.41E-03 6.64E-07 4.41E-03 9.82E-02 4.5 2,3,7,8-Tetrachlorodibenzo-p-dioxin (1746-01-6) 8.35E-09 0.00E+00 8.35E-09 0.0 9.51E-09 0.00E+00 9.51E-09 9.59E-09 0.00E+00 9.59E-09 2.74E-08 0.00E+00 2.74E-08 0.0 0.00E+00 2.74E-08 Organic HAP Total 1.43E+00 4.34E-03 1.44E+00 0.3 1.63E+00 1.45E-03 1.63E+00 1.64E+00 5.75E-03 1.65E+00 4.71E+00 1.15E-02 4.72E+00 0.2 8.09E-03 8.35E-07 8.09E-03 4.73E+00 0.2 Ci/yr % Ci/yr Ci/yr Ci/yr % Ci/yr % Radionuclides 7.35E-02 7.35E-02 0.0 8.11E-02 8.11E-02 4.17E-02 4.17E-02 1.96E-01 1.96E-01 7.03E-04 7.03E-04 1.97E-01 0.4
Notes:

(1)CY05 PAF coal-region proximate coal-quality data from Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. Unit-specific total coal-burn quantities listed in Excel file "CY05 Operating Statistics from DataFuser (012306).xls" on FPG Env Affr - TRI server were apportioned according to coal-region breakdown listed in Excel file "CoalStats2005.xls" in 1-19-06 e-mail fr. M.A. Pendley to J.D. Lokey (for PAF Units 1-2) or in previously cited Excel file in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. (PAF Unit 3); CEMS data from Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey; ash split to bottom ash from Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson 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 CY05 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). 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)CY01-CY05 filterable-PM stack test results from Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey.

(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)").

(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 CY05 selective-catalytic-reduction (SCR) process operational data & vendor-guaranteed SCR-exit max NH3 slip (2 ppmv dry basis) at 20,000 SCR operating hours. 07/12/06

Page 1 of 1

## BART
TVA Paradise Fossil Plant (PAF) BART Modeling Protocol Emission Estimates

**latitude longitude**  **Datum UTM East**  **UTM North UTM Zone**  **Datum deg.**  **deg. km**  **km ft**  **ft ft**  **ft/s deg F**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr** 

PAF1 TVA - PAF Unit 1 37.261 86.979 501.91 4123.61 16 600 422 26.0 72.6 125 4,371 321 3,695 686 527 2.39E-04 PAF2 TVA - PAF Unit 2 37.260 86.979 501.87 4123.56 16 600 422 26.0 72.6 125 4,528 321 3,692 676 522 2.49E-04 PAF3 TVA - PAF Unit 3 37.260 86.980 501.78 4123.48 16 800 422 26.79 134 327 26,477 372 5,090 852 723 3.04 **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 2

## BART

PAF1 PAF2 PAF3 **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) 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 %**  **% lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr lbs/hr**  **lbs/hr**

49 51 13.9 13.9 161 161 59.5 99.1 69.4 24.8 77.7 0.0 0.0 0.0 0.0 6.60 48 52 13.9 13.9 161 161 57.6 96.1 67.3 24.0 75.3 0.0 0.0 0.0 0.0 6.40 32 68 103 103 186 186 48.4 80.7 56.5 20.2 63.2 0.0 0.0 0.0 0.0 5.37

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 50 50 50 50 17.6 29.4 20.6 7.4 23.0 0.0 0.0 0.0 0.0 2.0
*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 07/12/06 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 2 of 2Inputs

**Table 7. Gaseous-Species Emission Parameters & Molecular Wts Table 8. 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) 0.008 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) 0.0014 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 Eastern Bituminous 0.016 Vol. I, 5th Edition, Supplement E, Section 1.1, "Bituminous and Subbituminous Mercury (Hg) 200.59

Western Bituminous 0.0022 Coal Combustion", Table 1.1-3, Sept. 98. Selenium (Se) 78.96 *Reference: Emission Factors Handbook (EFH) Guidelines for Estimating Trace Subbituminous (PRB) 0.003 Sulfur (S) 32.064 Substance Emissions from Fossil Fuel Steam Electric Plants, Electric Power Lignite 0.00112 **Table 6. 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 **Cyclone-Fired Boilers Burning Bituminous Coal*** Sulfur Trioxide (SO3) 80.0622 EFH Addenda and in the Apr. 2002 EFH revision. **Table 2. Air-Heater (AH) SO3/H2SO4 Penetration (F2) Factors*** Sulfuric Acid (H2SO4) 98.0774 Boiler Coal SO3/H2SO4 Penetration Particle Size Ammonia 17.0304 **Apr. 02 EFH Revision predicts Hg removal using correlation equations developed Type Type Factr ( = 1 - contrl efficncy) (Aerodynamic Nitrogen Oxides (NOx) as Nitrogen Dioxide (NO2) 46.0055 from 1999 ICR stack-test program results. Hg removal varies with chloride content All Low-S Eastern Bituminous (LSE) 0.49 Equiv. Diameter), Electrostatic of coal. Different correlation equations are listed for various types of air-pollution High-S Eastern Bituminous (HSE) 0.85 Micrometers Uncontrolled Precipitator (ESP) *Reference: PISCES Version 2.1 Release Notes, Addendum 3-6-98 control equipment. Western & Subbituminous (PRB) 0.90 10 13 68 6 8 56 **Reference: Chemical Engineers' Handbook, 5th Edition, Note: FGD = flue-gas desulfurization, e.g., limestone scrubber. **Table 3. PM-Control Eqpmt SO3/H2SO4 Penetratn (F2) Factrs*** 2.5 5.5 36 R.H. Perry & C.H. Chilton, Editors, 1973 Eqpmt Coal SO3/H2SO4 Penetration 1.25 5 22 Type Type Factr ( = 1 - contrl efficncy) 1 5 17 Cold-side Low-S Eastern Bituminous (LSE) 0.49 0.625 0 ESP High-S Eastern Bituminous (HSE) 0.77

Western & Subbituminous (PRB) 0.50 *Reference: US EPA, Compilation of Air Pollutant Emission Factors (AP-42), Hot ESP All 0.63 Vol. I, 5th Edition, Supplement E, Section 1.1, Table 1.1-8, Sept. 98. Bagfilter (BF)All 0.10 No data were given in Table 1.1-8 for particle-size distributions for cyclone coal-fired **Table 4. Wet/Dry FGD Eqpmt SO3/H2SO4 Penetratn (F2) Factrs*** boilers controlled by flue-gas-desulfurization (FGD) scrubbers, nor in size range below Eqpmt Coal SO3/H2SO4 Penetration 0.625 microns for any controls. PM-10 and PM-2.5 emssns for PAF Units 1-2 were Type Type Factr ( = 1 - contrl efficncy) estimated using the particle-size distribution for cyclone boilers controlled by ESP. Wet Spray Eastern Bituminous 0.47 Tower PRB/Lignite 0.40 **Table 6A. Fine Filterable PM (PM2.5_fil) Chemical Speciation*** Wet Venturi All 0.65 Dry FGD/BF All 0.01 Elemental Carbon (EC), Soil (e.g., flyash), Mg-Ox mixedAll 0.50 Equipment Type % of PM2.5_fil % of PM2.5_fil with fuel oil Coal-fired Boilers 3.7 96.3 Mg-Ox into All 0.50 furnace *Reference: US EPA, Draft "Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon", Jan. 2002, as cited in "Particulate Speciation Profiles Nominal Stack Flue-gas O2 Concentratn, % Vol = 6.0 for Selected Source Types" posted 3-16-06 on website providing CALPUFF modeling Nominal Flue-gas H2O Concentratn, % Vol = 8.1 information for VISTAS BART applications (http://vistas-sesarm.org/BART/calpuff.asp) NOTE: O2 concen. is used to estimate approx. SO3 volumetric concentration for **Table 6B. Total Condensable PM (CPM-TOT) Emission Factors*** comparison purposes. The SO3/H2SO4 mass emission rate (tpy) is estimated based on SO3/SO2 molar ratio, so precise O2 concen. aren't needed (changing Emission Factor (lb/10^6 Btu) vs. coal sulfur (S) content (%) the O2 concen. doesn't change the H2S04 mass emission rate, only ppm SO3). Equipment Type Coal S <= 0.4% by weight Coal S > 0.4% by weight PC Blr w/o FGD 0.01 =0.1*S-0.03 *Reference: "Estimating Sulfuric Acid Aerosol Emissions from Coal-Fired Power PC Blr w/ FGD 0.02 0.02 Plants", by R. Hardman, R. Stacy, & E. Dismukes. Paper presented at U.S. Cyclone Blr w/o FGD 0.01 =0.1*S-0.03 DOE-FETC Conference on Formation, Distribution, Impact, and Fate of Sulfur Cyclone Blr w/ FGD 0.02 0.02 Trioxide in Utility Flue Gas Streams, Pittsburgh, PA, 3-98; revised by K. Harrison, AFBC Blr 0.02 0.02 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, by **Table 6C. Condensable Particulate Matter (CPM) Chemical Speciation*** L.S. Monroe and K.E. Harrison, 12-02 (renamed "An Updated Method for Estimating Total Sulfuric Acid Emissions from Stationary Power Plants"), and Inorganic CPM (CPM-IOR), Organic CPM (CPM-ORG), by K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Equipment Type % of CPM-TOT % of CPM-TOT Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"). PC Blr w/o FGD 80 20 PC Blr w/ FGD ND, assume same as above ND, assume same as above Note: High-sulfur E. bituminous coal is defined as >= 2.5 % S, per 2-17-06 e-mail Cyclone Blr w/o FGD 80 20 from K.E. Harrison to J.D. Lokey et al. Cyclone Blr w/ FGD ND, assume same as above ND, assume same as above *Reference: US EPA, Compilation of Air Pollutant Emission Factors (AP-42), TVA Environmental Technologies Vol. I, 5th Edition, Supplement E, Section 1.1, Table 1.1-5, Sept. 98. 07/12/06 PM Cumulative Size Distribution, Cumulative Mass % < Stated Size **Table 1. Coal-fired Boiler SO3/H2SO4 Production (F1) Factors*** **Table 5. Uncontrolled Cyclone-Furnace Emission Factors***

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# 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 Pond Gypsum Sb 2.40 4.13 3.43 219 14.5 As 11.08 8.87 8.9 206 67.9 Ba 75.9 103.4 798 716 294 Be 1.66 1.37 3.09 28.2 8.8 Cd 1.05 0.92 2.67 19.0 5.17 Cl 625 494 67.0 686 4017 Cr 18.8 15.6 92 189 60.0 Co 13.0 10.5 57.7 124 43.0 Cu 12.2 11.5 39.2 262 56.8 F 8.78 15.9 38.5 373 82.1 Pb 18.7 15.0 17.9 336 108 Mn 40.1 35.5 342 128 84.4 Hg 0.113 0.111 0.316 0.30 0.201 Mo 12.0 10.2 42.5 170 54.5 Ni 16.8 14.9 81 220 59.2 Se 2.38 1.95 7.9 18.5 9.6 Ag 0.12 0.186 1.48 1.70 0.315 Tl 2.13 2.32 6.08 63.9 11.6 V 70.9 58.0 383 585 184 Zn 54.1 43.8 109 899 274 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 .

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**Sample Calculations for CY05 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 = 3,994,078tons/yr (tpy) CY05 PAF Units 1-2 as received/fired (AR) coal burn (total for all coal-supply regions) 1 coal_burn_PAF3 = 2,569,468tpy CY05 PAF Unit 3 AR coal burn (total for all coal-supply regions) 1 coal_burn_PAF1_2_ILB = 3,946,354tpy CY05 PAF Units 1-2 AR Illinois Basin (ILB) bituminous coal burn 1 coal_burn_PAF1_2_PRB = 47,724tpy CY05 PAF Units 1-2 AR Powder River Basin (PRB) subbituminous coal burn 1 coal_burn_PAF3_ILB = 745,146tpy CY05 PAF Unit 3 AR ILB bituminous coal burn 1 coal_burn_PAF3_PRB = 1,824,322tpy CY05 PAF Unit 3 AR PRB subbituminous coal burn 1 coal_burn_PAF1 = 1,866,460tpy CY05 PAF Unit 1 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF2 = 2,127,618tpy CY05 PAF Unit 2 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF3 = 2,569,468tpy CY05 PAF Unit 3 AR coal burn (total for all coal-supply regions) 2 coal_burn_PAF1_ILB_coal_stats = 1,847,875tpy CY05 PAF Unit 1 AR ILB bituminous coal burn (from PAF coal statistics) 3 coal_burn_PAF1_PRB_coal_stats = 18,585tpy CY05 PAF Unit 1 AR PRB subbituminous coal burn (from PAF coal statistics) 3 coal_burn_PAF2_ILB_coal_stats = 2,091,644tpy CY05 PAF Unit 2 AR ILB bituminous coal burn (from PAF coal statistics) 3 coal_burn_PAF2_PRB_coal_stats = 29,139tpy CY05 PAF Unit 2 AR PRB subbituminous coal burn (from PAF coal statistics) 3 coal_H2O_PAF_ILB = 12.2%-weight CY05 PAF ILB coal H2O content 1 coal_H2O_PAF_PRB = 27.5%-weight CY05 PAF PRB coal H2O content 1 coal_ash_PAF_ILB = 8.6%-weight CY05 PAF ILB coal AR ash content 1 coal_ash_PAF_PRB = 5.3%-weight CY05 PAF PRB coal AR ash content 1 coal_S_PAF_ILB = 2.69%-weight CY05 PAF ILB coal AR sulfur content 1 coal_S_PAF_PRB = 0.35%-weight CY05 PAF PRB coal AR sulfur content 1 coal_heat_PAF_ILB = 11,500 Btu [HHV]/lb CY05 PAF ILB coal AR heat content (higher heating value [HHV]) 1 coal_heat_PAF_PRB = 8,775Btu [HHV]/lb CY05 PAF PRB coal AR heat content (HHV) 1 PM_fil_emssn_factr_PAF1_coal = 0.071 lb/10^6 Btu (MBtu) Average of CY01-CY05 PAF Unit 1 coal-fired filterable particulate-matter (PM_fil) stack-test measurements 4 ash_partition_to_flue_gas_PAF = 25% TVA data for ash distribution in PAF cyclone-furnace coal-fired boilers 5 PM_fil_sub10_ESP = 68% Cumulative PM_fil mass % <= 10 micrometers for bituminous-fired cyclone blrs w/ electrostatic precipitator (ESP) 6 PM_fil_sub6_ESP = 56% Cumulative PM_fil mass % <= 6 micrometers for bituminous-fired cyclone blrs w/ ESP 6 PM_fil_sub2.5_ESP = 36% Cumulative PM_fil mass % <= 2.5 micrometers for bituminous-fired cyclone blrs w/ ESP 6 PM_fil_sub1.25_ESP = 22% Cumulative PM_fil mass % <= 1.25 micrometers for bituminous-fired cyclone blrs w/ ESP 6 PM_fil_sub1_ESP = 17% Cumulative PM_fil mass % <= 1.0 micrometers for bituminous-fired cyclone blrs w/ ESP 6 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 6 PM_cond_org_fractn = 20% Organic fraction (%) of total PM_cond emissns for cyclone blrs (use same factr as for pulverized-coal [PC] blrs) 6 CO_uncontrlld_emssn_factr_coal = 0.5lb/(ton AR coal) Uncontrolled carbon monoxide (CO) emssn factr for cyclone-fired blrs 6 VOC_uncontrlld_emssn_factr_coal = 0.11 lb/(ton AR coal) Uncontrolled volatile organic compound (VOC) emssn factr for cyclone-fired blrs 6 SO2_emssn_PAF1_CEMS = 13,563tpy CY05 PAF Unit 1 CEMS sulfur dioxide (SO2) emssn data (coal + alternate fuels) 7 NOx_emssn_PAF1_CEMS = 11,466tpy CY05 PAF Unit 1 CEMS nitrogen oxides (NOx) emssn data (coal + alternate fuels) 7 heat_input_PAF1_CEMS = 43,191,735x 10^6 Btu/yr (MBtu/yr) CY05 PAF Unit 1 CEMS heat-input estimate (coal + alternate fuels) 7 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 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) bitum. coal 8 Pb_in_PRB_mass = 3.2mg/kg (dry basis) Median Pb concentration in Powder River Basin (PRB) subbitum. coal 8 Cl_in_ILB_mass = 602 mg/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 Hg_in_ILB_mass = 0.08mg/kg (dry basis) Median mercury (Hg) concentration in ILB bitum. coal 8 Hg_in_PRB_mass = 0.06mg/kg (dry basis) Median Hg concentration in PRB subbitum. coal 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 Unit 1 Routine Coal-fired Criteria-Pollutant Emission Estimates:**  Coal-fired total filterable particulate-matter (PM_fil) emissions were estimated from average of CY01-CY05 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): coal_burn_PAF = coal_burn_PAF1_2+coal_burn_PAF3 coal_burn_PAF = 6,563,546tons/yr (tpy) Equation (2): coal_burn_PAF1_ILB = coal_burn_PAF1*coal_burn_PAF1_ILB_coal_stats/(coal_burn_PAF1_ILB_coal_stats+coal_burn_PAF1_PRB_coal_stats) coal_burn_PAF1_ILB = 1,847,875tpy CY05 PAF Unit 1 Illinois Basin (ILB) bitum. coal AR coal-burn quantity (burn share based on PAF coal stats) Equation (3): coal_burn_PAF1_PRB = coal_burn_PAF1*coal_burn_PAF1_PRB_coal_stats/(coal_burn_PAF1_ILB_coal_stats+coal_burn_PAF1_PRB_coal_stats) coal_burn_PAF1_PRB = 18,585tpy CY05 PAF Unit 1 Powder River Basin (PRB) subbitum. coal AR coal-burn quantity (burn share based on PAF coal stats) Equation (4): coal_burn_PAF2_ILB = coal_burn_PAF2*coal_burn_PAF2_ILB_coal_stats/(coal_burn_PAF2_ILB_coal_stats+coal_burn_PAF2_PRB_coal_stats) coal_burn_PAF2_ILB = 2,098,385tpy CY05 PAF Unit 2 ILB bitum. coal AR coal-burn quantity (burn share based on PAF coal stats) Equation (5): coal_burn_PAF2_PRB = coal_burn_PAF2*coal_burn_PAF2_PRB_coal_stats/(coal_burn_PAF2_ILB_coal_stats+coal_burn_PAF2_PRB_coal_stats) coal_burn_PAF2_PRB = 29,233tpy CY05 PAF Unit 2 PRB subbitum. coal AR coal-burn quantity (burn share based on PAF coal stats) Equation (6): heat_input_PAF1_ILB = coal_burn_PAF1_ILB*(2000 lb/ton)*coal_heat_PAF_ILB*(TBtu/10^12 Btu) heat_input_PAF1_ILB = 42.50TBtu/yr Equation (7): heat_input_PAF1_PRB = coal_burn_PAF1_PRB*(2000 lb/ton)*coal_heat_PAF_PRB*(TBtu/10^12 Btu) heat_input_PAF1_PRB = 0.33TBtu/yr Equation (8): heat_input_PAF1_coal = heat_input_PAF1_ILB+heat_input_PAF1_PRB heat_input_PAF1_coal = 42.83TBtu/yr Equation (9): 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 = 1.53E+03 tpy This value is listed in cell F21 of "PAF1" wksheet (PAF1!F21) and also in cell B13 of "air" worksheet. Equation (10): PM_fil_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM_fil_emssn_factr_PAF1_coal PM_fil_emssn_PAF1_coal_hrly = 4.96E+02lb/unit-hr This value, listed in cell PAF1!G21, is based on average PM_fil emssn factr & Title V max heat-input capacity. Equation (11): PM10_fil_emssn_PAF1_coal = PM_fil_emssn_PAF1_coal*PM_fil_sub10_ESP/100 PM10_fil_emssn_PAF1_coal = 1.04E+03 tpy This value is listed in cell PAF1!F22 and also in cell B14 of "air" worksheet. Equation (12): 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 = 4.84E-02lb/MBtu Equation (13): PM10_fil_emssn_PAF1_coal_hrly = max_heat_input_PAF1*PM10_fil_emssn_factr_PAF1_coal

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PM10_fil_emssn_PAF1_coal_hrly = 3.37E+02lb/unit-hr This value, listed in cell PAF1!G22, is based on average PM10_fil emssn factr & Title V max heat-input capacity. Equation (14): PM2.5_fil_emssn_PAF1_coal = PM_fil_emssn_PAF1_coal*PM_fil_sub2.5_ESP/100 PM2.5_fil_emssn_PAF1_coal = 5.49E+02 tpy This value is listed in cell PAF1!F23 and also in cell B15 of "air" worksheet. Equation (15): 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 = 2.56E-02lb/MBtu Equation (16): 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 = 1.78E+02lb/unit-hr This value, listed in cell PAF1!G23, is based on average PM2.5_fil emssn factr & Title V max heat-input capacity. Equation (17): 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 = 6.60E+00lb/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 = 4.28E+02 tpy This value is listed in cell PAF1!F24 and also in cell B16 of "air" worksheet. 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+02lb/unit-hr This value, listed in cell PAF1!G24, is based on average 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. 6 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 = 5.95E+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 = 9.91E+01 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 = 6.94E+01 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 = 2.48E+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 = 8.43E+01 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 = 7.77E+01 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*CO_uncontrlld_emissn_factr_coal*(ton/2000 lb) CO_emssn_PAF1_coal = 4.67E+02 tpy This value is listed in cell PAF1!F27 and also in cell B19 of "air" worksheet. Equation (2): CO_emssn_factr_PAF1_coal = CO_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) CO_emssn_factr_PAF1_coal = 2.18E-02lb/MBtu Equation (3): CO_emssn_PAF1_coal_hrly = max_heat_input_PAF1*CO_emssn_factr_PAF1_coal CO_emssn_PAF1_coal_hrly = 1.52E+02lb/unit-hr This value, listed in cell PAF1!G27, is based on average CO emssn factr & Title V max heat-input capacity. Volatile Organic Compounds (VOC) Equation (1): VOC_emssn_PAF1_coal = coal_burn_PAF1*VOC_uncontrlld_emissn_factr_coal*(ton/2000 lb) VOC_emssn_PAF1_coal = 1.03E+02 tpy This value is listed in cell PAF1!F28 and also in cell B20 of "air" worksheet. Equation (2): VOC_emssn_factr_PAF1_coal = VOC_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) VOC_emssn_factr_PAF1_coal = 4.79E-03lb/MBtu Equation (3): VOC_emssn_PAF1_coal_hrly = max_heat_input_PAF1*VOC_emssn_factr_PAF1_coal VOC_emssn_PAF1_coal_hrly = 3.34E+01 lb/unit-hr This value, listed in cell PAF!G28, is based on average VOC emssn factr & Title V max heat-input capacity. 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

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SO2_emssn_factr_PAF1_CEMS = 6.28E-01 lb/MBtu Equation (2): SO2_emssn_PAF1_coal_hrly = max_heat_input_PAF1*SO2_emssn_factr_PAF1_CEMS SO2_emssn_PAF1_coal_hrly = 4.37E+03lb/unit-hr This value, listed in cell PAF1!G25, is based on CY05-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 = 5.31E-01 lb/MBtu Equation (2): NOx_emssn_PAF1_coal_hrly = max_heat_input_PAF1*NOx_emssn_factr_PAF1_CEMS NOx_emssn_PAF1_coal_hrly = 3.69E+03lb/unit-hr This value, listed in cell PAF1!G26, is based on CY05-average CEMS NOx emssn factr & Title V max heat-input capacity.

**PA F Unit 1 Routine 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_EB = 1.6% SO3/SO2 ratio for cyclone-fired boilers burning Eastern bituminous (EB) 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 = 0.3% 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 = 10% 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 = 50% 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 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 = 7,397hours/year (hr/yr) PAF Unit 1 boiler total in-service hours 2 SCR_operatn_hrs_PAF1 = 3586hr/yr PAF Unit 1 selective-catalytic-reduction (SCR) reactor total in-service hours (in flue-gas path) 13 SCR_NH3_operatn_hrs_PAF1 = 3185hr/yr PAF Unit 1 SCR reactor in-service hours (with ammonia [NH3] feed) 13 SCR_SO2_oxidatn_rate = 0.75% PAF design SCR-reactor catalyst SO2 oxidation rate 14 NH3_slip = 2 ppmv 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 flue_gas_SO3_concen_stk_PAF_SCR_byp_FGD = 14.2 ppmvd 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 Coal-fired Boiler Combustion-Derived SO3/H2SO4 Manufacture/Emission Estimates (HSD Method): PAF Unit 1 Illinois Basin (ILB) bituminous coal: Equation (1): Blr_exit_SOx_PAF1_ILB = coal_burn_PAF1_ILB*coal_S_PAF_ILB/100*bitum_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF1_ILB = 9.43E+04tpy Equation (2): Blr_H2SO4_productn_PAF1_ILB = Blr_exit_SOx_PAF1_ILB*SO3_to_SO2_molar_ratio_EB/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF1_ILB = 2.31E+03tpy Equation (3): Blr_H2SO4_emssn_PAF1_ILB = Blr_H2SO4_productn_PAF1_ILB*(1-AH_SO3_contrl_effncy_EB/100)*(1-WV_SO3_contrl_effncy/100) Blr_H2SO4_emssn_PAF1_ILB = 1.28E+03tpy PAF Unit 1 ILB-coal boiler combustion-derived contributn to SO3/H2SO4 stack emissns (HSD Method) PAF Unit 1 Powder River Basin (PRB) subbituminous coal: Equation (4): Blr_exit_SOx_PAF1_PRB = coal_burn_PAF1_PRB*coal_S_PAF_PRB/100*subbit_S_to_SOx/100*SO2_mol_wt/S_mol_wt Blr_exit_SOx_PAF1_PRB = 1.14E+02tpy Equation (5): Blr_H2SO4_productn_PAF1_PRB = Blr_exit_SOx_PAF1_PRB*SO3_to_SO2_molar_ratio_sub/100*H2SO4_to_SO3_molar_ratio*H2SO4_mol_wt/SO2_mol_wt Blr_H2SO4_productn_PAF1_PRB = 5.22E-01 tpy Equation (6): Blr_H2SO4_emssn_PAF1_PRB = Blr_H2SO4_productn_PAF1_PRB*(1-AH_SO3_contrl_effncy_WC/100)*(1-WV_SO3_contrl_effncy/100) Blr_H2SO4_emssn_PAF1_PRB = 3.06E-01 tpy PAF Unit 1 PRB-coal boiler combustion-derived contributn to SO3/H2SO4 stack emissns (HSD Method)
PAF Unit 1 total-coal boiler combustion-derived SO3/H2SO4 emssn: Equation (7): Blr_H2SO4_productn_PAF1_coal = Blr_H2SO4_productn_PAF1_ILB+Blr_H2SO4_productn_PAF1_PRB Blr_H2SO4_productn_PAF1_coal = 2.31E+03tpy Equation (8): Blr_H2SO4_emssn_PAF1_coal = Blr_H2SO4_emssn_PAF1_ILB+Blr_H2SO4_emssn_PAF1_PRB Blr_H2SO4_emssn_PAF1_coal = 1.28E+03tpy PAF Unit 1 coal-fired blr combustn-derived contributn to SO3/H2SO4 emissns (HSD method)--not used for CY05 estimates Equation (9): Blr_H2SO4_contrl_effncy_PAF1 = (1-Blr_H2SO4_emssn_PAF1_coal/Blr_H2SO4_productn_PAF1_coal)*100 Blr_H2SO4_contrl_effncy_PAF1 = 44.75% Equation (10): Blr_H2SO4_flue_gas_concen_PAF1 = Blr_H2SO4_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_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_PAF1 = 2.06E+01 ppmvd Coal-fired blr combustion-derived contributn to PAF Unit 1 stk-exit SO3/H2SO4 flue-gas concentration (HSD Method).

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Selective-catalytic-reduction (SCR) Reactor-Derived SO3/H2SO4 Emission Estimates (HSD Method): PAF Unit 1 Illinois Basin (ILB) bituminous coal: Equation (1): SCR_oper_factr_PAF1 = SCR_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 SCR_oper_factr_PAF1 = 4.85E-01 (dimensionless) Nominal fraction of PAF Unit 1 coal burn while SCR reactor was in flue-gas path Equation (2): SCR_H2SO4_productn_PAF1_ILB = Blr_exit_SOx_PAF1_ILB*SCR_SO2_oxidatn_rate/100*SCR_oper_factr_PAF1*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF1_ILB = 5.25E+02tpy Equation (3): SCR_NH3_oper_factr_PAF1 = SCR_NH3_operatn_hrs_PAF1/blr_operatn_hrs_PAF1 SCR_NH3_oper_factr_PAF1 = 4.31E-01 (dimensionless) Fraction of PAF Unit 1 coal burn while SCR reactor was in flue-gas path with NH3 inputs Equation (4): NH3_neutrlztn_PAF1_ILB = heat_input_PAF1_ILB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF1*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_PAF1_ILB = 5.36E+01 tpy PAF Unit 1 ILB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip. Equation (5): SCR_H2SO4_emssn_PAF1_ILB = (SCR_H2SO4_productn_PAF1_ILB-NH3_neutrlztn_PAF1_ILB)*(1-AH_SO3_contrl_effncy_EB/100)*(1-WV_SO3_contrl_effncy/100) SCR_H2SO4_emssn_PAF1_ILB = 2.61E+02tpy PAF Unit 1 ILB-coal-fired boiler SCR-derived contributn to SO3/H2SO4 stack emissns (HSD Method) PAF Unit 1 Powder River Basin (PRB) subbituminous coal: Equation (6): SCR_H2SO4_productn_PAF1_PRB = Blr_exit_SOx_PAF1_PRB*SCR_SO2_oxidatn_rate/100*SCR_oper_factr_PAF1*H2SO4_mol_wt/SO2_mol_wt SCR_H2SO4_productn_PAF1_PRB = 6.33E-01 tpy H2SO4 Equation (7): NH3_neutrlztn_PAF1_PRB = heat_input_PAF1_PRB*(10^6 MBtu/TBtu)*SCR_NH3_oper_factr_PAF1*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_PAF1_PRB = 4.08E-01 tpy H2SO4 PAF Unit 1 PRB-coal-fired SO3/H2SO4 quantity neutralized by NH3 slip. Equation (8): SCR_H2SO4_emssn_PAF1_PRB = (SCR_H2SO4_productn_PAF1_PRB-NH3_neutrlztn_PAF1_PRB)*(1-AH_SO3_contrl_effncy_WC/100)*(1-WV_SO3_contrl_effncy/100) SCR_H2SO4_emssn_PAF1_PRB = 1.32E-01 tpy H2SO4 PAF Unit 1 PRB-coal-fired boiler SCR-derived contributn to SO3/H2SO4 stack emissns (HSD Method)
PAF Unit 1 Total-coal SCR-derived SO3/H2SO4 Emission Estimate: Equation (9): SCR_H2SO4_productn_PAF1_coal = SCR_H2SO4_productn_PAF1_ILB + SCR_H2SO4_productn_PAF1_PRB SCR_H2SO4_productn_PAF1_coal = 5.26E+02tpy H2SO4 Equation (10): SCR_H2SO4_emssn_PAF1_coal = SCR_H2SO4_emssn_PAF1_ILB + SCR_H2SO4_emssn_PAF1_PRB SCR_H2SO4_emssn_PAF1_coal = 2.61E+02tpy H2SO4 SCR-derived contributn to PAF Unit 1 SO3/H2SO4 stk emissions, per HSD method (not used for CY05 estimates) Equation (11): SCR_H2SO4_contrl_effncy_PAF1_coal = (1-SCR_H2SO4_emssn_PAF1_coal/SCR_H2SO4_productn_PAF1_coal)*100 SCR_H2SO4_contrl_effncy_PAF1_coal = 50.42% Equation (12): SCR_H2SO4_flue_gas_concen_PAF1 = SCR_H2SO4_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_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_PAF1 = 4.20E+00ppmvd SCR-derived contributn to annual-average PAF Unit 1 flue-gas SO3/H2SO4 concentration (HSD Method). PAF Unit 1 Total Coal-fired SO3/H2SO4 Emission Estimates (HSD Method): Equation (1): H2SO4_productn_PAF1_coal_HSD = Blr_H2SO4_productn_PAF1_coal+SCR_H2SO4_productn_PAF1_coal H2SO4_productn_PAF1_coal_HSD = 2.84E+03tpy Equation (2): H2SO4_emssn_PAF1_coal_HSD = Blr_H2SO4_emssn_PAF1_coal+SCR_H2SO4_emssn_PAF1_coal H2SO4_emssn_PAF1_coal_HSD = 1.54E+03tpy PAF Unit 1 coal-fired blr- & SCR-derived contributn to SO3/H2SO4 emissns (HSD method)--not used for CY05 estimates. Equation (3): H2SO4_contrl_effncy_PAF1_coal_HSD = (1-H2SO4_emssn_PAF1_coal/H2SO4_productn_PAF1_coal)*100 H2SO4_contrl_effncy_PAF1_coal_HSD = 45.80% Equation (4): H2SO4_stk_gas_concen_PAF1_coal_HSD = H2SO4_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu)/flue_gas_factr_dry*(20.9-flue_gas_O2_concen)/20.9/H2SO4_conv_factr H2SO4_stk_gas_concen_PAF1_coal_HSD = 2.48E+01 ppmvd PAF Unit 1 total SO3/H2SO4 stack-exit flue-gas concentration (HSD Method). PAF Unit 1 Total Coal-fired SO3/H2SO4 Emission Estimates (Flue-Gas-Concentration Method): Equation (1): flue_gas_SO3_concen_stk_exit_PAF1_avg = flue_gas_SO3_concen_stk_PAF_SCR_byp_FGD*(1-SCR_oper_factr_PAF1)+flue_gas_SO3_concen_stk_PAF_SCR_FGD*SCR_oper_factr_PAF1 flue_gas_SO3_concen_stk_exit_PAF1_avg = 1.59E+01 ppmvd at 3% O2 Equation (2): 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 = 9.88E+02tpy H2SO4 PAF Unit 1 coal-fired blr- & SCR-derived contributn to SO3/H2SO4 emissns, listed in PAF1!F29 and in air!B21. Equation (3): H2SO4_emssn_factr_PAF1_coal = H2SO4_emssn_PAF1_coal*(2000lb/ton)/heat_input_PAF1_coal*(TBtu/10^6 MBtu) H2SO4_emssn_factr_PAF1_coal = 4.61E-02lb/MBtu Equation (4): H2SO4_emssn_PAF1_coal_hrly = max_heat_input_PAF1*H2SO4_emssn_factr_PAF1_coal H2SO4_emssn_PAF1_coal_hrly = 3.21E+02lb/unit-hr This value, listed in cell PAF1!G29, is based on average H2SO4 emssn factr & Title V max heat-input capacity. Equation (5): H2SO4_contrl_effncy_PAF1_coal = (1-H2SO4_emssn_PAF1_coal/H2SO4_productn_PAF1_coal_HSD)*100 H2SO4_contrl_effncy_PAF1_coal = 65.18%

**PA F Unit 1 Routine CY05 Ammonia (NH3) Emission Estimates**  General Input Variables: Value Units Notes Reference blr_operatn_hrs_PAF1 = 7,397hours/year (hr/yr) PAF Unit 1 boiler total in-service hours 2 blr_operatn_hrs_PAF2 = 8,452hr/yr PAF Unit 2 boiler total in-service hours 2 blr_operatn_hrs_PAF3 = 5,705hr/yr PAF Unit 3 boiler total in-service hours 2 SCR_NH3_operatn_hrs_PAF1 = 3,185hr/yr PAF Unit 1 selective-catalytic-reduction (SCR) reactor total in-service hours (with NH3 inputs) 13 SCR_NH3_operatn_hrs_PAF2 = 3,811 hr/yr PAF Unit 2 SCR reactor total in-service hours (with NH3 inputs) 13 SCR_NH3_operatn_hrs_PAF3 = 3,072hr/yr PAF Unit 3 SCR reactor total in-service hours (with NH3 inputs) 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 = 2 ppmv 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 anhydrous_NH3_recpts_truck = 988,000lb/yr CY05 PAF anhydrous NH3 receipts by truck 18 anhydrous_NH3_recpts_rail = 18,800,924lb/yr CY05 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 = 0.001 dimensionless 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

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T1_BF_EB = 0.10dimensionless Penetration of gaseous NH3 through bagfilter (BF) in units burning EB coal 17 T1_WFGD_EB = 0.01 dimensionless 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 = 0.01 dimensionless 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 = 0.56275dimensionless Penetration of gaseous NH3 through AH in units burning Rocky Mtn bituminous (RMB) coal 20 T1_POST_APH_FGC_RMB = 0.26275dimensionless 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 = 0.7375dimensionless Penetration of gaseous NH3 through BF in units burning RMB coal 20 T1_WFGD_RMB = 0.01 dimensionless Penetration of gaseous NH3 through WFGD scrubber in units burning RMB coal 20 T1_DFGD_BF_RMB = 0.184375dimensionless 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 = 0.6375dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning RMB coal w/ SO3 FGC 20 T5_AH_RMB = 0.3375dimensionless Fraction of NH3 adsorbed on particles (and NH4 salts) & penetrating AH in units burning RMB coal 20 T6_CS_ESP = 0.01 dimensionless 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 = 0.038dimensionless CY05 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 = 0.016dimensionless 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 = 0.7625dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by AH in units burning RMB coal 20 E1_CS_ESP_RMB_air = 0.7375dimensionless 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 = 0.7375dimensionless Fug. air-release fractn of NH3 adsorbed on particles (& NH4 salts) captured by BF in units burning RMB coal 20 E1_WFGD_RMB_air = 0.7625dimensionless 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 = 44,460lb/yr PAF plant-total boiler-water-treatment (BWT) aqueous NH3 receipts 18 aqueous_NH3_wt_fractn = 35% Unless otherwise indicated, presumed weight percent NH3 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 = 125,672tons/yr (tpy) PAF flyash production 5 FA_dry_sales = 0tpy No CY05 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) 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 = 795,712tpy 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 = 946,174tpy Equation (4): coal_burn_PAF1_2_ILB_SCR = coal_burn_PAF1_ILB_SCR+coal_burn_PAF2_ILB_SCR coal_burn_PAF1_2_ILB_SCR = 1,741,886tpy 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 = 4.98E+11 std 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 = 4.04E+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 = 4.04E-01 lb/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 = 1.14E+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 = 6.24E+03lb/yr Equation (10): coal_burn_PAF3_ILB_SCR = coal_burn_PAF3_ILB*SCR_NH3_operatn_hrs_PAF3/blr_operatn_hrs_PAF3 coal_burn_PAF3_ILB_SCR = 401,258tpy Equation (11): flue_gas_flow_PAF3_ILB_SCR = coal_burn_PAF3_ILB_SCR*(2000lb/ton)*coal_heat_PAF_ILB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF3_ILB_SCR = 1.15E+11 std ft^3/yr Equation (12): SCR_exit_NH3_mass_rate_PAF3_ILB = flue_gas_flow_PAF3_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_ILB = 9.31E+03lb/yr Equation (13): NH3_stk_emssn_PAF3_ILB = SCR_exit_NH3_mass_rate_PAF3_ILB*T1_AH_EB*T1_CS_ESP_EB NH3_stk_emssn_PAF3_ILB = 9.31E+00lb/yr Equation (14): NH4_salt_stk_emssn_PAF3_ILB = SCR_exit_NH3_mass_rate_PAF3_ILB*T5_AH_EB*T6_CS_ESP NH4_salt_stk_emssn_PAF3_ILB = 6.98E+01 lb/yr Equation (15): SCR_NH3_fugitive_emssn_PAF3_ILB = SCR_exit_NH3_mass_rate_PAF3_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_ILB = 7.83E+02lb/yr PAF Powder River Basin (PRB) subbituminous coal:

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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 = 8,003tpy 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 = 13,181 tpy Equation (3): coal_burn_PAF1_2_PRB_SCR = coal_burn_PAF1_PRB_SCR+coal_burn_PAF2_PRB_SCR coal_burn_PAF1_2_PRB_SCR = 21,184tpy 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 = 4.62E+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 = 3.75E+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 = 2.81E+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 = 2.82E+00lb/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_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 = 3.35E+02lb/yr Equation (9): coal_burn_PAF3_PRB_SCR = coal_burn_PAF3_PRB*SCR_NH3_operatn_hrs_PAF3/blr_operatn_hrs_PAF3 coal_burn_PAF3_PRB_SCR = 982,390tpy Equation (10): flue_gas_flow_PAF3_PRB_SCR = coal_burn_PAF3_PRB_SCR*(2000lb/ton)*coal_heat_PAF_PRB*(MBtu/10^6 Btu)*flue_gas_factr_wet_3%O2 flue_gas_flow_PAF3_PRB_SCR = 2.14E+11 std ft^3/yr Equation (11): SCR_exit_NH3_mass_rate_PAF3_PRB = flue_gas_flow_PAF3_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_PRB = 1.74E+04lb/yr Equation (12): NH3_stk_emssn_PAF3_PRB = SCR_exit_NH3_mass_rate_PAF3_PRB*T1_AH_PRB*T1_CS_ESP_PRB NH3_stk_emssn_PAF3_PRB = 1.30E+04lb/yr Equation (13): NH4_salt_stk_emssn_PAF3_PRB = SCR_exit_NH3_mass_rate_PAF3_PRB*T5_AH_PRB*T6_CS_ESP NH4_salt_stk_emssn_PAF3_PRB = 3.48E+01 lb/yr Equation (14): SCR_NH3_fugitive_emssn_PAF3_PRB = SCR_exit_NH3_mass_rate_PAF3_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_PRB = 3.35E+03lb/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)*coal_burn_PAF1_ILB_SCR/coal_burn_PAF1_2_ILB_SCR*(ton/2000 lb) NH3_stk_emssn_PAF1_coal = 7.35E-04tons/yr (tpy) CY05 PAF Unit 1 gaseous NH3 stack emissions, listed in cell PAF1!F30 and also in cell B22 of "air" 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 = 3.43E-08lb/MBtu Equation (3): NH3_emssn_PAF1_coal_hrly = max_heat_input_PAF1*NH3_emssn_factr_PAF1_coal NH3_emssn_PAF1_coal_hrly = 2.39E-04lb/unit-hr This value, listed in cell PAF1!G30, is based on CY05-average 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)*coal_burn_PAF1_ILB_SCR/coal_burn_PAF1_2_ILB_SCR*(ton/2000 lb) NH4_salt_stk_emssn_PAF1_coal = 2.61E-01 tpy 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_PAF = 1.07E+04lb/yr 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 = 1.56E+01 lb/yr Equation (3): BWT_NH3_fugitive_emssn_PAF = aqueous_NH3_rcpts*aqueous_NH3_wt_fractn/100*BWT_pond_NH3_air BWT_NH3_fugitive_emssn_PAF = 1.56E+03lb/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 = 6.14E+00tpy CY05 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) 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 = 2.18E+01 lb/10^12 Btu (TBtu) = EFH Median Pb Emission Correlation Estimate 10

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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 = 1.07E+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 = 97.96% = 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 = 4.63E-01 tpy 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 = 8.45E+00lb/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 = 2.64E+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 = 96.81 % = 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 = 1.38E-03tpy This value is listed in cell F41 of "PAF1_PRB" worksheet (PAF1_PRB!F41).

PAF Unit 1 total-coal Pb emssn: Equation (9): Pb_emssn_PAF1_coal = Pb_emssn_PAF1_ILB+Pb_emssn_PAF1_PRB Pb_emssn_PAF1_coal = 4.64E-01 tpy This value is listed in cell PAF1!F41 and is included in cell B35 of "air" worksheet. Equation (10): Pb_in_coal_energy_PAF1 = (Pb_in_ILB_energy*heat_input_PAF1_ILB+Pb_in_PRB_energy*heat_input_PAF1_PRB)/heat_input_PAF1_coal Pb_in_coal_energy_PAF1 = 1.06E+03lb/TBtu Equation (11): Pb_emssn_factr_PAF1_coal = Pb_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal Pb_emssn_factr_PAF1_coal = 2.17E+01 lb/TBtu Equation (12): Pb_emssn_PAF1_coal_hrly = max_heat_input_PAF1*Pb_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) Pb_emssn_PAF1_coal_hrly = 1.51E-01 lb/unit-hr This value, listed in cell PAF1!G41, is based on average Pb emssn factr & Title V max heat-input capacity. Equation (13): Pb_contrl_effncy_PAF1 = (1-Pb_emssn_factr_PAF1_coal/Pb_in_coal_energy_PAF1)*100 Pb_contrl_effncy_PAF1 = 97.96% 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 = 5.23E+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 = 1.62E+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 = 3.43E+01 tpy 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): Cl_in_PRB_energy = Cl_in_PRB_mass*(kg/10^6 mg)/coal_heat_PAF_PRB*(10^12 Btu/TBtu) Cl_in_PRB_energy = 5.70E+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 = 1.76E+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 = 2.87E-02tpy This value is listed in cell PAF1_PRB!F52.
PAF Unit 1 total-coal HCl emssn: Equation (7): HCl_emssn_PAF1_coal = HCl_emssn_PAF1_ILB+HCl_emssn_PAF1_PRB HCl_emssn_PAF1_coal = 3.44E+01 tpy This value is listed in cell PAF1!F52 and is included in air!B30. Equation (8): Cl_in_coal_energy_PAF = (Cl_in_ILB_energy*heat_input_PAF1_ILB+Cl_in_PRB_energy*heat_input_PAF1_PRB)/heat_input_PAF1_coal Cl_in_coal_energy_PAF = 5.20E+04lb/TBtu Equation (9): HCl_emssn_factr_uncontrolld_PAF_coal = Cl_in_coal_energy_PAF*HCl_mol_wt/Cl_mol_wt HCl_emssn_factr_uncontrolld_PAF_coal = 5.35E+04lb/TBtu Equation (10): HCl_emssn_factr_PAF1_coal = HCl_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal HCl_emssn_factr_PAF1_coal = 1.60E+03lb/TBtu Equation (11): HCl_emssn_PAF1_coal_hrly = max_heat_input_PAF1*HCl_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) HCl_emssn_PAF1_coal_hrly = 1.12E+01 lb/unit-hr This value, listed in cell PAF1!G52, is based on average HCl emssn factr & Title V max heat-input capacity. Equation (12): 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

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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 = 6.11E+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 = 18.69% 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 = 51.32% Equation (5): Hg_emssn_factr_PAF1_ILB = Hg_in_ILB_energy*(1-Hg_contrl_effncy_PAF1_ILB/100) Hg_emssn_factr_PAF1_ILB = 2.97E+00lb/TBtu Equation (6): Hg_emssn_PAF1_ILB = Hg_emssn_factr_PAF1_ILB*heat_input_PAF1_ILB*(ton/2000 lb) Hg_emssn_PAF1_ILB = 6.32E-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 = 4.96E+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 = 5.32% 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 = 4.69E+00lb/TBtu Equation (10): Hg_emssn_PAF1_PRB = Hg_emssn_factr_PAF1_PRB*heat_input_PAF1_PRB*(ton/2000 lb) Hg_emssn_PAF1_PRB = 7.65E-04tpy This value is listed in cell PAF1_PRB!F54. PAF Unit 1 total-coal Hg emssn: Equation (11): Hg_emssn_PAF1_coal = Hg_emssn_PAF1_ILB+Hg_emssn_PAF1_PRB Hg_emssn_PAF1_coal = 6.39E-02tpy This value is listed in cell PAF1!F54 and is included in air!B37. Equation (12): Hg_in_coal_energy_PAF = (Hg_in_ILB_energy*heat_input_PAF1_ILB+Hg_in_PRB_energy*heat_input_PAF1_PRB)/heat_input_PAF1_coal Hg_in_coal_energy_PAF = 6.10E+00lb/TBtu Equation (13): Hg_emssn_factr_PAF1_coal = Hg_emssn_PAF1_coal*(2000 lb/ton)/heat_input_PAF1_coal Hg_emssn_factr_PAF1_coal = 2.99E+00lb/TBtu Equation (14): Hg_emssn_PAF1_coal_hrly = max_heat_input_PAF1*Hg_emssn_factr_PAF1_coal*(TBtu/10^6 MBtu) Hg_emssn_PAF1_coal_hrly = 2.08E-02lb/unit-hr This value, listed in cell PAF1!G54, is based on average Hg emssn factr & Title V max heat-input capacity. Equation (15): Hg_contrl_effncy_PAF1_coal = (1-Hg_emssn_factr_PAF1_coal/Hg_in_coal_energy_PAF)*100 Hg_contrl_effncy_PAF1_coal = 51.0% PAF Unit 1 coal-region weighted-avg. boiler/SCR/FGD total-coal Hg 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 = 3.43E-03tpy = PAF Unit 1 biphenyl emission estimate, listed in cell PAF1!F73 and included in air!B67.

**PA F Unit 1 Routine Coal-fired Radionuclide Emission Estimates:**  Radionuclides_in_fly_ash = 53.1 pCi/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 = 1.72E+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 = 7.35E-02Ci/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 = 179,956gal/yr CY05 PAF Units 1-2 distillate (No. 2) fuel-oil burn. 2 turbine_startups_PAF1 = 12 Number of CY05 PAF Unit 1 turbine startups 2 turbine_startups_PAF1_2 = 16 Number of CY05 PAF Units 1-2 total turbine startups 2 lightoff_oil_heat_PAF = 138,500 Btu/gal CY05 PAF plant-total lightoff-oil heat content (HHV) 2 lightoff_oil_S_PAF = 0.2% weight CY05 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

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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 = 0.061 lb/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_PAF*turbine_startups_PAF1/turbine_startups_PAF lightoff_oil_burn_PAF1 = 134,967gal/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 = 1.35E-01 tpy 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 = 1.92E+00tpy 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 = 1.62E+00tpy 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 = 3.37E-01 tpy 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 = 1.35E-02tpy This value is listed in Table 11 of the "alt_fuel" wksheet & is included in air!C20. Sulfuric Acid (H2SO4) Equation (7): 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 = 9.42E-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 = 8.41E-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 = 4.12E-03tpy 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 = 16,335gallons/yr (gal/yr) CY05 PAF Unit 1 used-oil burn 22 specific_grav = 0.9g/mL Nominal value for TVA-wide used-oil samples 23 used_oil_ash = 0.1 weight % 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 = 51 lb/(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 = 1 lb/kgal Volatile organic compds (VOC) uncontrolled emissn factr for used-oil combustion in boilers 24 PM_fil_emssn_factr_PAF1_coal = 0.071 lb/10^6 Btu (MBtu) CY05 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 = 13,563tons/yr (tpy) CY05 PAF Unit 1 CEMS sulfur dioxide (SO2) emssn data (coal + alternate fuels) 7 heat_input_PAF1_CEMS = 43,191,735x 10^6 Btu/yr (MBtu/yr) CY05 PAF Unit 1 CEMS heat-input estimate (coal + alternate fuels) 7 NOx_emssn_PAF1_CEMS = 11,466tpy CY05 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 = 2.42 mg/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 = 97.96% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E40 in "PAF1" wksheet) HCl_contrl_effncy_PAF1 = 97.00% PAF Unit 1 coal-region weighted-avg. boiler/FGD total-coal HCl control efficiency (cell E51 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 = 5.23E-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 coal_ash_PAF1 = 8.57%-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 coal_heat_PAF1 = 1.15E+04 Btu [HHV]/lb AR basis

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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 = 1.87E+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 = 96.2% 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 = 1.99E-03tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$13. Sulfur Dioxide (SO2) Equation (7): coal_S_PAF1 = (coal_burn_PAF1_ILB*coal_S_PAF_ILB+coal_burn_PAF1_PRB*coal_S_PAF_PRB)/coal_burn_PAF1 coal_S_PAF1 = 2.67%-weight (AR basis) Equation (8): SO2_uncontrlld_emssn_factr_PAF1_coal = (SOx_uncontrlld_emssn_factr_bitum*coal_S_PAF1_ILB*coal_burn_PAF1_ILB+ SOx _uncontrlld_emssn_factr_subbit*coal_S_PAF1_PRB*coal_burn_PAF1_PRB)/(coal_heat_PAF1*coal_burn_PAF1*2000 lb/ton)*(10^6 Btu/MBtu) SO2_uncontrlld_emssn_factr_PAF1_coal = 4.42E+00lb/MBtu Equation (9): SO2_emssn_factr_PAF1_CEMS = SO2_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS SO2_emssn_factr_PAF1_CEMS = 6.28E-01 lb/MBtu Equation (10): SO2_contrl_effncy_PAF1 = (1-SO2_emssn_factr_PAF1_CEMS/SO2_uncontrlld_emssn_factr_PAF1_coal)*100 SO2_contrl_effncy_PAF1 = 85.78% Equation (11): SO2_emssn_PAF1_used_oil = used_oil_burn_PAF1*SO2_emssn_factr_used_oil*(kgal/1000 gal)*used_oil_S*(1-SO2_contrl_effncy_PAF1/100)*(ton/2000 lb) SO2_emssn_PAF1_used_oil = 6.83E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$17. Nitrogen Oxides (NOx) Equation (12): NOx_uncontrlld_emssn_factr_PAF1_coal = (NOx_uncontrlld_emssn_factr_bitum*coal_burn_PAF1_ILB+NOx_uncontrlld_emssn_factr_subbit*coal_burn_PAF1_PRB)/(coal_heat_PAF1*coal_burn_PAF1*2000 lb/ton)*(10^6 Btu/MBtu) NOx_uncontrlld_emssn_factr_PAF1_coal = 1.43E+00lb/MBtu Equation (13): NOx_emssn_factr_PAF1_CEMS = NOx_emssn_PAF1_CEMS*(2000 lb/ton)/heat_input_PAF1_CEMS NOx_emssn_factr_PAF1_CEMS = 5.31E-01 lb/MBtu Equation (14): NOx_contrl_effncy_PAF1 = (1-NOx_emssn_factr_PAF1_CEMS/NOx_uncontrlld_emssn_factr_PAF1_coal)*100 NOx_contrl_effncy_PAF1 = 62.91 % Equation (15): NOx_emssn_PAF1_used_oil = used_oil_burn_PAF1*NOx_emssn_factr_used_oil*(kgal/1000 gal)*(1-NOx_contrl_effncy_PAF1/100)*(ton/2000 lb) NOx_emssn_PAF1_used_oil = 5.76E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$18. Carbon Monoxide (CO) Equation (16): CO_emssn_PAF1_used_oil = used_oil_burn_PAF1*CO_emssn_factr_used_oil*(kgal/1000 gal)*(1-CO_contrl_effncy_PAF1/100)*(ton/2000 lb) CO_emssn_PAF1_used_oil = 4.08E-02tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$C$19. Volatile Organic Compounds (VOC) Equation (17): VOC_emssn_PAF1_used_oil = used_oil_burn_PAF1*VOC_emssn_factr_used_oil*(kgal/1000 gal)*(1-VOC_contrl_effncy_PAF1/100)*(ton/2000 lb) VOC_emssn_PAF1_used_oil = 8.17E-03tpy This value is listed in Table 4 of the "alt_fuel" wksheet & is included in air!$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 = 1.49E-04tpy Equation (2): Pb_emssn_PAF1_used_oil = Pb_inputs_PAF1_used_oil*(1-Pb_contrl_effncy_PAF1/100) Pb_emssn_PAF1_used_oil = 3.0E-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 = 2.9E-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) CY05 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 = 97.96% 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 CY05 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-01 lb/MBtu

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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+00 MBtu/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) CY05 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 = 4,372 Btu/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-01 lb/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-01 lb/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 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/coal_burn_PAF WW_burn_PAF1 = 0.00E+00tpy CY05 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-01 lb/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 CY05 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 = 97.96% PAF Unit 1 coal-region weighted-avg. boiler/FGD Pb contrl effncy (cell E41 in "PAF1" wksheet)

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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 CY05 process quantities (Ref. 33) to estimate CY05 fugitive-dust emissions. See Ref. 32 for sample calculations.
**References:** (1) Excel file "CY 2005 TRI Coal Data.xls" in 2-3-06 e-mail from S.A. Godbehere to J.D. Eady et al. (2) Excel file "CY05 Operating Statistics from DataFuser (012306).xls" in CY 05\Release Estimates\Operating Stats folder on FPG Env Affr - TRI ("chapgfs5") server. (3) Excel file "CoalStats2005.xls" in 1-19-06 e-mail from M.A. Pendley to J.D. Lokey. (4) Excel file "Current Particulate Test Reports Updated 02032006.xls" in 2-8-06 e-mail from W.C. Markham to J.D. Lokey. (5) Excel file "TRI Report CY05.xls" in 2-14-06 e-mail from E.C. Miller to C.M. Anderson et al. (6) 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. (7) Excel file "TVA Historic Emissions Excel 95 version.xls" in 2-15-06 e-mail from W.M. Sisk to J.D. Lokey. (8) 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); 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). (9) Chloride (Cl) concentrations reflect TVA's CY99 Information Collection Request (ICR) analyses at PAF (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 K.E. Harrison, L.S. Monroe, & J.E. Cichanowicz, 10-05 (renamed "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants: Revision 3 (2005)"). (13) Excel file "TRI CY05 Fossil Questionnaire.xls" dated 2-16-06, archived in the CY 05\Completed Questionnaires\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 3-13-06 e-mails from K.J. Dukes to M.F. Broder et al, archived in CY 05\Completed Questionnaires\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 6 in "NH3" worksheet) (20) TVA interpolation for Rocky Mtn bituminous (RMB) coal penetration & environmental factors from Ref. 17, weighted according to relative alkaline contents of RMB, PRB subbituminous, & Eastern bituminous 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 "PAFAtt1 Oper StatsReport CY 2005.xls" in 2-10-06 e-mail from M.A. Pendley 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 "Alternative Fuels TRI Data CY2005.xls," in 2-3-06 e-mail from S.A. Godbehere to R.W. Burbage et al. (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 "2005 Chemicals used for Fossil Boiler Cleanings 1-13-06.doc" in CY 05\Release Estimates\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 "Coal and Limestone Handled in CY 2005.xls" in 2-3-06 e-mail from S.L. Priddy to C.M. Anderson et al. (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). TVA Environmental Technologies 07/12/06

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