Facility _Information

facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_type

legal_address

legal_city legal_state legal_zip 645 18454 Tampa Electric Tampa Electric

operator 13031 W ya ndotte Rd Apollo Beach

FL 33572 7242 18454 Tampa Electric Tampa Electric

operator 9995 State Road 37 South Mulberry FL 33860

Page 1Facility _Information

plant_nam e

physical_address

phyical_city

physical_state

physical_zip

ma iling_address

ma iling_city

ma iling_state

ma iling_zip Big Bend 13031 W ya ndotte Rd Apollo Beach

FL 33572 13031 W ya ndotte Rd Apollo Beach

FL 33572 Polk 9995 State Road 37 South Mulberry FL 33860 9995 State Road 37 South Mulberry FL 33860

Page 2Facility _Information

RFA_small_entity

ff_fired_coal

ff_fired_oil ff_fired_ngas ff_fired_petcoke

ff_fired_other

ff_permitted_coal

ff_permitted_oil

ff_permitted_ngas Don't Know TRUE TRUE FALSE TRUE TRUE TRUE TRUE FALSE Don't Know TRUE TRUE FALSE TRUE FALSE TRUE TRUE FALSE

Page 3Facility _Information

ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note TRUE TRUE Excess emissions are required to be reported within 1 business day to the compliance regulatory agency . Other deviation reporting is done semi-annually . Reports of deviations from permit requirements, semi-annual monitoring reports, annual operating reports - all required by state rule No Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) TRUE FALSE Reports of deviations from permit requirements, semi-annual monitoring reports, annual operating reports - all required by state rule No Gross efficiency is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 4Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 5Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 6Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 7Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency, steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 8Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency, steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 9Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 10Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 11Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 12Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 13Facility _Information

Operation of the SCR for unit 1 is not planned to commence operation until May 2010, but the unit was taken out of service during the last quarter of 2009.Design and current operating efficiency , steam pressure and steam temperature varry acording to operating cycles, addition of control devices and boiler combustion optimization for emission purposes. As indidcated in the TV permit, steam boiler generating Unit 1 is rated at 4037 MMBtu/hr, Unit 2 at 3996 MMBtu/hr, Unit 3 at 4115 MMBtu/hr and Unit 4 at 4330 MMBtu/hr, but these are understood to not be a instaneous limits and dialogue with the regulatory agency is ongoing to determine the applicable averaging period. Additionally , comparison of design and operating efficiencies is difficult to compare even at initial operation, operating data would not be the same as design data. Net efficiencies are very difficult to allocate and have a greater margin of confidence due to variations in station service power requirements (e.g. various fans, pumps, ect ...) Gross efficiency

is not relevant (not calculated) for IGCC plants due to the high auxiliary powerload.Design net efficiency : 38.6% HHVPresent operating net efficiency : 33.4% HHV (month of January , 2010)Individual efficiencies for CT and ST are not relevant for IGCC due to heavy interactions between the gasification plant and CT and ST.NOx Control:N2 dilution has been the primary means of NOx abatement since initial operation. In addition, a saturator was installed and went on line (05/2003) to provide supplemental NOx control.PM Control:Syngas PM scrubbing (water deluge) has been primary means of PM control since initial operation (10/1996). Saturator also provides some addiitional fuel gas water wash.Additional fuel gas fileter was added for turbine protection but also provides some particulate removal (06/1998)Unit 1 regulated under NSPS Subpart GGPolk Unit 1 is a demonstration plant done in conjunction with DOE, emission rates are not guaranteed rather, were demonstrated

Page 14facility _contacts

facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 645 2 Principal Engineer Joshua Ellwein

8132284433

8136951692

jdellwein@tecoenergy .com

TRUE 7242 1 Principal Engineer Joshua Ellwein

8132284433

8136951692

jdellwein@tecoenergy .com

TRUE

Page 15facility _coal_utilized

facility _id coal_type percentage_mass percentage_btu

synfuel_type

coal_note 645 petroleum coke 1.4 2 645 subbituminous 98.6 98 7242 petroleum coke 73 78 Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke. 7242 subbituminous 27 22 Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke.

Page 16facility _coal_utilized

Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke. Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke.

Page 17facility _coal_utilized

Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke. Gasification of petroleum coke and coal blend. Each shipment receipt varies slightly for petcoke/coal on a mass basis as solid fuel is blended to 5.2 lb S / MMBtu. Blending ratio is dependant on sulfur content of petcoke.

Page 18facility _oil_utilized

facility _id oil_type percentage_volume percentage_btu

other_type 645 No.2 Fuel Oil (distillate) 100 100 7242 No.2 Fuel Oil (distillate) 100 100

Page 19facility _other_materials

facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain 645 Ecotherm FALSE TRUE 992.84 tons/year No Tampa Electric would have to evaluate the benefit of recycling the Ecotherm compared to be subject to CAA section 129.

Page 20facility _other_materials

rcra_explain Tampa Electric would have to evaluate the benefit of recycling the Ecotherm compared to be subject to CAA section 129.

Page 21facility _other_materials

Tampa Electric would have to evaluate the benefit of recycling the Ecotherm compared to be subject to CAA section 129.

Page 22boiler_information

facility _id boiler_id boiler_type boiler_other bottom_design

design_fuel heat_input max_heat_input MW e_capacity 645 1 Wa ll firing - opposed firing Wet Bottom

coal 4037 4037 410 645 2 Wa ll firing - opposed firing Wet Bottom

coal 3996 3996 410 645 3 Wa ll firing - opposed firing Wet Bottom

coal 4115 4115 400 645 4 Tangential firing Dry Bottom coal 4330 4330 465 7242 1 IGCC coal

Page 23boiler_information

MW e_net_capacity

design_gross_efficiency

operating_gross_efficiency

design_pressure

operating_pressure

design_temp

operating_temp

design_reheat_multiple

design_reheat_temp1 385 38 34 2875 2550 1000 1000 FALSE 1000 385 38 35 2875 2550 1000 1000 FALSE 1000 375 39 35 2875 2550 1000 1000 FALSE 1000 432 38 35 2990 2750 1005 1000 FALSE 1005 FALSE

Page 24boiler_information

design_reheat_temp2

operating_reheat_multiple

operating_reheat_temp1

operating_reheat_temp2

hours_operated

vg_capacity

_factor applicable_NSPS

retirement_year

retirement_year_CBI FALSE 1000 6897 79 Subpart D FALSE FALSE 1000 6214 71 Subpart D FALSE FALSE 1000 5925 68 Subpart D FALSE FALSE 1000 6684 76 Subpart Da(1) FALSE FALSE 6843 78 FALSE

Page 25boiler_information

NOx_control

SO2_control

combustion_additives Yes No No Yes No No Yes No No Yes No No Yes Yes No

Page 26boiler_fuels

facility _id boiler_id fuel_type fuel_year percentage_massvol percentage_btu

other_type 645 1 coal - subbituminous 2007 99.9 100 645 1 coal - subbituminous 2008 99.8 100 645 1 coal - subbituminous 2009 97 97 645 1 petroleum coke 2007 0.1 0 645 1 petroleum coke 2008 0.2 0 645 1 petroleum coke 2009 3 3 645 2 coal - subbituminous 2007 100 100 645 2 coal - subbituminous 2008 99.5 100 645 2 coal - subbituminous 2009 99 99 645 2 petroleum coke 2008 0.5 0 645 2 petroleum coke 2009 1 1 645 3 coal - subbituminous 2007 99.96 100 645 3 coal - subbituminous 2008 99 99 645 3 coal - subbituminous 2009 98 98 645 3 petroleum coke 2007 0.04 0 645 3 petroleum coke 2008 1 1 645 3 petroleum coke 2009 2 2 645 4 coal - subbituminous 2007 99.69 100 645 4 coal - subbituminous 2008 99.9 100 645 4 coal - subbituminous 2009 99.81 100 645 4 other non-fossil fuel (specify) 2009 0.05 0 Ecotherm 645 4 petroleum coke 2007 0.31 0 645 4 petroleum coke 2008 0.1 0 645 4 petroleum coke 2009 0.14 0 7242 1 coal - subbituminous 2007 39 34 7242 1 coal - subbituminous 2008 31 26 7242 1 coal - subbituminous 2009 26 21 7242 1 oil - distillate 2007 2 2 7242 1 oil - distillate 2008 2 2 7242 1 oil - distillate 2009 2 2 7242 1 petroleum coke 2007 59 64 7242 1 petroleum coke 2008 67 72 7242 1 petroleum coke 2009 72 77

Page 27boiler_control_NOx

facility _id boiler_id NOx_type NOx_other NOx_online 645 1 Low NOx Burner 3/1/2001 645 2 Low NOx Burner 3/1/2001 645 3 Low NOx Burner 3/1/2001 645 4 Advanced Overfire Air 4/1/2003 7242 1 Other (specify) N2 dilution 10/1/1996

Page 28boiler_control_SO2

facility _id boiler_id SO2_type SO2_other SO2_online 7242 1 Other (specify) sulfuric acid plant in conjunction with MDEA acid gas removal system

7/1/1996

Page 29boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online

Page 30facility _units

facility _id unit_id 645 001 645 002 645 003 645 004 7242 001

Page 31unit_boilers

facility _id unit_id boiler_id 645 001 1 645 002 2 645 003 3 645 004 4 7242 001 1

Page 32facility _controls

facility _id control_id control_group control_type

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 645 BB01_PM PM control Electrostatic precipitator, hot side, w/o flue gas conditioning FALSE 10/1/1970 645 BB02_PM PM control Electrostatic precipitator, hot side, w/o flue gas conditioning FALSE 4/1/1973 645 BB02_post_SCR

NOx control

Selective Cataly

tic Reduction FALSE 5/1/2009 Am mo nia 645 BB03_PM PM control Electrostatic precipitator, hot side, w/o flue gas conditioning FALSE 5/1/1976 645 BB03_post_SCR

NOx control

Selective Cataly

tic Reduction FALSE 7/1/2008 Am mo nia 645 BB03_Scrubber

SO2 control

Packed type FALSE 1/1/2008 645 BB04_PM PM control Electrostatic precipitator, hot side, w/o flue gas conditioning FALSE 2/1/1985 645 BB04_post_SCR

NOx control

Selective Cataly

tic Reduction FALSE 6/1/2007 Am mo nia 645 BB04_Scrubber

SO2 control

Packed type FALSE 1/1/2008 645 BB1and2_Scrubber

SO2 control

Packed type FALSE 12/1/1999 645 BB3and4_Scrub_Combin

SO2 control

Packed type FALSE 2/1/1985

Page 33facility _controls

reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive

0

0 Lim estone No

0 Lim estone No Lim estone No Lim estone No

Page 34facility _sampling_ports

facility _id sampling_port_id 645 BB03/CS03_test_port 645 BB04/CS02_test_port 645 CS001_test_port 645 CS0W 1_test_port 7242 HRSG 7242 HRSG Sampling Port

Page 35facility _stacks

facility _id stack_id stack_height stack_diameter

sack_gas_velocity 645 BB03/CS03 645 BB04/CS02 645 CS001 645 CS0W 1 499 29.83 7242 HRSG

Page 36configurations

facility _id configuration_id 645 BB01_pre-SCR 645 BB02_pre-SCR 645 BB02_SCR 645 BB03_pre_SCR 645 BB03_SCR_iso 645 BB04_pre_SCR 645 BB04_SCR_iso 645 BB04_SCR_noniso 7242 IGCC1

Page 37configuration_components

facility _id configuration_id

component_id

order component_type port_near 645 BB01_pre-SCR

001 1 Unit 645 BB01_pre-SCR

BB01_PM 2 PM control 645 BB01_pre-SCR

BB1and2_Scrubber 3 SO2 control 645 BB01_pre-SCR

CS0W 1 5 Stack 645 BB01_pre-SCR

CS0W 1_test_port 4 Sam pling Port next 645 BB02_pre-SCR

002 1 Unit 645 BB02_pre-SCR

BB02_PM 2 PM control 645 BB02_pre-SCR

BB1and2_Scrubber 3 SO2 control 645 BB02_pre-SCR

CS0W 1 5 Stack 645 BB02_pre-SCR

CS0W 1_test_port 4 Sam pling Port next 645 BB02_SCR002 1 Unit 645 BB02_SCR BB02_PM 3 PM control 645 BB02_SCR BB02_post_SCR 2 NOx control 645 BB02_SCR BB1and2_Scrubber 4 SO2 control 645 BB02_SCRCS0W 1 6 Stack 645 BB02_SCRCS0W 1_test_port 5 Sam pling Port next 645 BB03_pre_SCR

003 1 Unit 645 BB03_pre_SCR

BB03/CS03 5 Stack 645 BB03_pre_SCR

BB03/CS03_test_port

4 Sam pling Port

next 645 BB03_pre_SCR

BB03_PM 2 PM control 645 BB03_pre_SCR

BB3and4_Scrub_Combin

3 SO2 control 645 BB03_SCR_iso

003 1 Unit 645 BB03_SCR_iso

BB03/CS03 6 Stack 645 BB03_SCR_iso

BB03/CS03_test_port

5 Sam pling Port

next 645 BB03_SCR_iso

BB03_PM 3 PM control 645 BB03_SCR_iso

BB03_post_SCR 2 NOx control 645 BB03_SCR_iso

BB03_Scrubber 4 SO2 control 645 BB04_pre_SCR

004 1 Unit 645 BB04_pre_SCR

BB04/CS02 5 Stack 645 BB04_pre_SCR

BB04/CS02_test_port

4 Sam pling Port

next 645 BB04_pre_SCR

BB04_PM 2 PM control 645 BB04_pre_SCR

BB3and4_Scrub_Combin

3 SO2 control 645 BB04_SCR_iso

004 1 Unit 645 BB04_SCR_iso

BB04/CS02 6 Stack 645 BB04_SCR_iso

BB04/CS02_test_port

5 Sam pling Port

next 645 BB04_SCR_iso

BB04_PM 3 PM control 645 BB04_SCR_iso

BB04_post_SCR 2 NOx control 645 BB04_SCR_iso

BB04_Scrubber 4 SO2 control 645 BB04_SCR_noniso

004 1 Unit 645 BB04_SCR_noniso

BB04/CS02 6 Stack 645 BB04_SCR_noniso

BB04/CS02_test_port

5 Sam pling Port

next 645 BB04_SCR_noniso

BB04_PM 3 PM control 645 BB04_SCR_noniso

BB04_post_SCR 2 NOx control 645 BB04_SCR_noniso

BB3and4_Scrub_Combin

4 SO2 control 7242 IGCC1 001 1 Unit 7242 IGCC1 HRSG 2 Stack 7242 IGCC1 HRSG Sampling Port 3 Sam pling Port

pevious

Page 38configuration_pollutants1

facility _id configuration_id

pollutant_nam e

permit_type_1

em lim it_1 em lim it_units_1 avg_period_1

em lim it_2 em lim it_units_2 645 BB02_pre-SCR

Sulfur Dioxide (SO2)

Federal - PSD Permit

6.5 pound per million British Thermal Unit (lb/MMBtu)

2 hours 645 BB02_pre-SCR

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.84 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB02_pre-SCR

PM (Filterable)

Fderal - PSD Permit

0.03 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB02_SCR Nitrogen Oxide (NOx) Federal - PSD Permit

0.12 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB02_SCRSulfur Dioxide (SO2) Federal - PSD Permit

0.25 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB02_SCR PM (Filterable) Fderal - PSD Permit

0.03 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB03_pre_SCR

Sulfur Dioxide (SO2)

Federal - PSD Permit

6.5 pound per million British Thermal Unit (lb/MMBtu)

2 hours 645 BB03_pre_SCR

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.7 pound per million British Thermal Unit (lb/MMBtu)

30 days 0.84 pound per million British Thermal Unit (lb/MMBtu) 645 BB03_pre_SCR

PM (Filterable)

Fderal - PSD Permit

0.03 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB03_SCR_iso

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.12 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB03_SCR_iso

Sulfur Dioxide (SO2)

Federal - PSD Permit

0.25 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB03_SCR_iso

PM (Filterable)

Fderal - PSD Permit

0.03 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB04_pre_SCR

Sulfur Dioxide (SO2)

Federal - PSD Permit

0.82 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_pre_SCR

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.6 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_pre_SCR

Carbon Monoxide (CO)

Federal - PSD Permit

0.029 pound per million British Thermal Unit (lb/MMBtu)

3 hours 124 pound per hour (lb/hr) 645 BB04_pre_SCR

PM (Filterable)

Fderal - PSD Permit

0.01 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB04_SCR_iso

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.1 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_SCR_iso

Sulfur Dioxide (SO2)

Federal - PSD Permit

0.82 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_SCR_iso

PM (Filterable)

Fderal - PSD Permit

0.01 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB04_SCR_iso

Carbon Monoxide (CO)

Federal - PSD Permit

0.2 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_SCR_noniso

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.1 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_SCR_noniso

Sulfur Dioxide (SO2)

Federal - PSD Permit

0.82 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB04_SCR_noniso

PM (Filterable)

Fderal - PSD Permit

0.01 pound per million British Thermal Unit (lb/MMBtu)

3 hours 645 BB04_SCR_noniso

Carbon Monoxide (CO)

Federal - PSD Permit

0.2 pound per million British Thermal Unit (lb/MMBtu)

30 days 645 BB01_pre-SCR

Nitrogen Oxide (NOx)

Federal - PSD Permit

0.84 pound per million British Thermal Unit (lb/MMBtu)

30 days 7242 IGCC1 Nitrogen Oxide (NOx) Federal - PSD Permit

15 parts per million by

volum e (dry) (ppmvd) 30 days 7242 IGCC1 VOCs Federal - PSD Permit 3 pound per hour (lb/hr)

30 days 7242 IGCC1 Carbon Monoxide (CO) Federal - PSD Permit

98 pound per hour (lb/hr)

30 days 7242 IGCC1 PM (Filterable) Fderal - PSD Permit

17 pound per hour (lb/hr)

30 days 7242 IGCC1 Lead (Pb) Federal - PSD Permit 0.0035 pound per hour (lb/hr)

30 days 7242 IGCC1 Sulfur Dioxide (SO2) Federal - PSD Permit

357 pound per hour (lb/hr)

30 days 7242 IGCC1 Sulfuric Acid Federal - PSD Permit

55 pound per hour (lb/hr)

30 days 7242 IGCC1 Arsenic (As) Federal - PSD Permit

0.0006 pound per hour (lb/hr)

30 days 7242 IGCC1 Beryllium (Be) Federal - PSD Permit

0.0001 pound per hour (lb/hr)

30 days 7242 IGCC1 me rcury Federal - PSD Permit 0.0034 pound per hour (lb/hr)

30 days 645 BB01_pre-SCR

PM (Filterable)

Fderal - PSD Permit

0.03 pound per million British Thermal Unit (lb/MMBtu)

2 hours 530 tons per year (tons/yr) 645 BB01_pre-SCR

Sulfur Dioxide (SO2)

Federal - PSD Permit

6.5 pound per million British Thermal Unit (lb/MMBtu)

2 hours

Page 39configuration_pollutants1

avg_period_2

em lim it_3 em lim it_units_3 avg_period_3

em lim it_4 em lim it_units_4 avg_period_4

em lim it_details

test_method

pound per million British Thermal Unit (lb/MMBtu)

3 hours

Continuous

Page 40configuration_pollutants1

em rate em rate_units guarantee_level

_explain

req_monitoring

eq_recordkeeping

req_reporting No No No No No No No No No No No No No No No No No No No No No No No No No 25 parts per million by

volum e (dry) (ppmvd) No CEMS 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance 1 parts per million by

volum e (dry) (ppmvd) No Title-V Renewal 40 CFR 60.7, Notification and Recordkeeping

NSPS Excess Emissions and Monitoring System Performance 25 parts per million by

volum e (dry) (ppmvd) No Annual Com pliance Stack Test 40 CFR 60.7, Notification and Recordkeeping

NSPS Excess Emissions and Monitoring System Performance 17 pound per hour (lb/hr)

No VE test done annually VE test submittal into regulatory agency , 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No Initial Only 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No CEMS 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No Sem i-Annual 40 CFR 60.7, Notification and Recordkeeping

NSPS Excess Emissions and Monitoring System Performance No Initial Only 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No Initial Only 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No Initial Only 40 CFR 60.7, Notification and Recordkeeping NSPS Excess Emissions and Monitoring System Performance No No

Page 41configuration_pollutants1

NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance NSPS Excess Emissions and Monitoring System Performance

Page 42control_technologies

facility _id configuration_id

component_id

control_id project_title project_type vendor_name

vndor_contact

vendor_phone

Page 43control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive

Page 44control_technologies

injection_point

HAP_em ission_reduction

HAP_em ission_rate

HAP_em ission_rate_units

HAP_achieved_reduction

HAP_achieved_rate

HAP_achieved_rate_units

feed_rate feed_rate_units

Page 45control_technologies

feed_rate_units

Page 46control_coal_ranks

facility _id configuration_id

component_id

control_id coal_type

Page 47control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e

Page 48control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year

Page 49control_costs

CBI

Page 50mi sc_controls

facility _id mi sc_control_id

control_description

Page 51mi sc_control_configurations

facility _id mi sc_control_id

configuration_id

Page 52fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_type state_country other_country

county

Page 53fuel_shipments

coal_seam shipment_method

Page 54fuel_shipment_configurations

facility _id shipment_id

configuration_id

Page 55fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units

Page 56fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_type

supplier_name

supplier_address

Page 57fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies

Page 58fuel_shipment_samples

analysis_copies

Page 59fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL

Page 60test_reports

facility _id report_id report_type other_type report_description report_begin_date

report_end_date

before_control

during_deviation 645 BB#1_FY2007

compliance Annaul Com pliance 5/17/2007 No No 645 BB#1_FY2008

compliance Annual Com pliance 3/12/2008 No No 645 BB#1_FY2009

compliance Annual Com pliance 2/25/2009 No No 645 BB#2_29_SEP_2005

compliance 29-Sep-2005 Report 9/29/2005 No No 645 BB#2_FY2005

compliance Annual Com pliance 2/25/2005 2/25/2005 No No 645 BB#2_FY2006

compliance Annual Com pliance ######## ######## No No 645 BB#2_FY2007

compliance Annaul Com pliance ######## No No 645 BB#2_FY2008

compliance Annual Com pliance 4/2/2008 No No 645 BB#3_FY2005

compliance 2/25/2005 2/25/2005 No No 645 BB#3_FY2006

compliance Annaul Com pliance 3/8/2006 No No 645 BB#3_FY2007

compliance Annaul Com pliance 4/5/2007 No No 645 BB#3_FY2008

compliance Annual Com pliance 8/27/2008 No No 645 BB#3_FY2009

compliance Annual Com pliance 6/3/2009 No No 645 BB#4_ECOTHERM

compliance ECOTherm Product Test burn results 9/17/2009 No No 645 BB#4_FY2006

compliance Annaul Com pliance 4/25/2006 No No 645 BB#4_FY2007

compliance Annual Com pliance 9/11/2007 No No 645 BB#4_FY2008

compliance Annual Com pliance 4/16/2008 No No 645 BB#4_FY2009

compliance Annual Com pliance 5/21/2009 No No 7242 Polk#1_FY2007

compliance Annual Com pliance 12/1/2006 No No 7242 Polk#1_FY2008

compliance Annual Com pliance 1/8/2008 No No 7242 Polk#1_FY2009

compliance Annual Com pliance and Title V Renewal Activities ######## ######## No No 7242 Polk#1_OIL2005

compliance Compliance on Fuel Oil 8/23/2005 No No 7242 Polk#1_SAM2005

compliance Sulfuric Acid Mist 2005 5/18/2005 No No 7242 Polk#1_SAM2006

compliance Sulfuric Acid Mist Annual 2/7/2006 No No 7242 Polk#1_SAM2009

compliance SAM Septem ber 20009 8/27/2009 9/1/2009 No No 7242 Polk#1_SynGas2006

compliance Annual Com pliance 1/18/2006 No No 7242 Polk#1_VOC and SAM Retest

compliance VOC and SAM Retest 1/15/2009 1/16/2009 No No 7242 Polk#1_VOC Retest

compliance VOC Retest4/16/2009 No No

Page 61test_reports

deviation_reports No No No No No No No No No No No No No No No No No No No No Yes No No No No No Yes No

Page 62test_report_configurations

facility _id report_id configuration_id 645 BB#1_FY2007

BB01_pre-SCR 645 BB#1_FY2008

BB01_pre-SCR 645 BB#1_FY2009

BB01_pre-SCR 645 BB#2_29_SEP_2005

BB02_pre-SCR 645 BB#2_FY2005

BB02_pre-SCR 645 BB#2_FY2006

BB02_pre-SCR 645 BB#2_FY2007

BB02_pre-SCR 645 BB#2_FY2008

BB02_pre-SCR 645 BB#3_FY2005

BB03_pre_SCR 645 BB#3_FY2006

BB03_pre_SCR 645 BB#3_FY2007

BB03_pre_SCR 645 BB#3_FY2008

BB03_pre_SCR 645 BB#3_FY2009

BB03_SCR_iso 645 BB#4_ECOTHERM

BB04_SCR_iso 645 BB#4_FY2006

BB04_pre_SCR 645 BB#4_FY2007

BB04_SCR_iso 645 BB#4_FY2008

BB04_SCR_iso 645 BB#4_FY2009

BB04_SCR_iso 7242 Polk#1_FY2007

IGCC1 7242 Polk#1_FY2008

IGCC1 7242 Polk#1_FY2009

IGCC1 7242 Polk#1_OIL2005

IGCC1 7242 Polk#1_SAM2005

IGCC1 7242 Polk#1_SAM2006

IGCC1 7242 Polk#1_SAM2009

IGCC1 7242 Polk#1_SynGas2006

IGCC1 7242 Polk#1_VOC and SAM Retest

IGCC1 7242 Polk#1_VOC Retest

IGCC1

Page 63test_report_fuels

facility _id report_id fuel_id 645 BB#1_FY2007

matrix 645 BB#1_FY2008

matrix 645 BB#1_FY2009

matrix 645 BB#2_29_SEP_2005

compliance 645 BB#2_FY2005

Low_Sulfur 645 BB#2_FY2006

compliance 645 BB#2_FY2006

Low_Sulfur 645 BB#2_FY2007

compliance 645 BB#2_FY2008

compliance 645 BB#3_FY2005

Compliance 645 BB#3_FY2006

compliance 645 BB#3_FY2007

compliance 645 BB#3_FY2008

matrix 645 BB#3_FY2009

matrix 645 BB#4_ECOTHERM

Eco Therm mix 645 BB#4_FY2006

matrix 645 BB#4_FY2007

matrix 645 BB#4_FY2008

matrix 645 BB#4_FY2009

matrix 7242 Polk#1_FY2007

Syngas 7242 Polk#1_FY2008

Syngas 7242 Polk#1_FY2009

Syngas 7242 Polk#1_OIL2005

#2 Fuel Oil 7242 Polk#1_SAM2005

Syngas 7242 Polk#1_SAM2006

Syngas 7242 Polk#1_SAM2009

Syngas 7242 Polk#1_SynGas2006

Syngas 7242 Polk#1_VOC and SAM Retest

Syngas 7242 Polk#1_VOC Retest

Syngas

Page 64test_report_fuel_types

facility _id report_id fuel_id fuel_type percentage_massvol percentage_btu

other_type 645 BB#1_FY2007

matrix coal - bituminous 84 84 645 BB#1_FY2007

matrix coal refuse 4 4 645 BB#1_FY2007

matrix petroleum coke 12 12 645 BB#1_FY2008

matrix coal - bituminous 86 86 645 BB#1_FY2008

matrix coal refuse 4 4 645 BB#1_FY2008

matrix petroleum coke 10 10 645 BB#1_FY2009

matrix coal - bituminous 88 88 645 BB#1_FY2009

matrix petroleum coke 12 12 645 BB#2_29_SEP_2005

compliance coal - bituminous 100 100 645 BB#2_FY2005

Low_Sulfur coal - bituminous 100 100 645 BB#2_FY2006

compliance coal - bituminous 100 100 645 BB#2_FY2006

Low_Sulfur coal - bituminous 100 100 645 BB#2_FY2007

compliance coal - bituminous 100 100 645 BB#2_FY2008

compliance coal - bituminous 100 100 645 BB#3_FY2005

Compliance

coal - bituminous 100 100 645 BB#3_FY2006

compliance coal - bituminous 100 100 645 BB#3_FY2007

compliance coal - bituminous 100 100 645 BB#3_FY2008

matrix coal - bituminous 94 94 645 BB#3_FY2008

matrix coal refuse 1 1 645 BB#3_FY2008

matrix petroleum coke 5 5 645 BB#3_FY2009

matrix coal - bituminous 87 87 645 BB#3_FY2009

matrix petroleum coke 13 13 645 BB#4_ECOTHERM

Eco Therm mix

coal - bituminous 96 96 645 BB#4_ECOTHERM

Eco Therm mix

other fossil fuel (specify)

4 4 ECOTherm product 645 BB#4_FY2006

matrix coal - bituminous 90 90 645 BB#4_FY2006

matrix petroleum coke 10 10 645 BB#4_FY2007

matrix coal - bituminous 90 90 645 BB#4_FY2007

matrix coal refuse 1 1 645 BB#4_FY2007

matrix petroleum coke 9 9 645 BB#4_FY2008

matrix coal - bituminous 86 86 645 BB#4_FY2008

matrix coal refuse 4 4 645 BB#4_FY2008

matrix petroleum coke 10 10 645 BB#4_FY2009

matrix coal - bituminous 85 85 645 BB#4_FY2009

matrix petroleum coke 15 15 7242 Polk#1_FY2007

Syngas coal - synfuel 100 100 7242 Polk#1_FY2008

Syngas coal - synfuel 100 100 7242 Polk#1_FY2009

Syngas coal - synfuel 100 100 7242 Polk#1_OIL2005

#2 Fuel Oil oil - distillate 100 100 7242 Polk#1_SAM2005

Syngas coal - synfuel 100 100 7242 Polk#1_SAM2006

Syngas coal - synfuel 100 100 7242 Polk#1_SAM2009

Syngas coal - synfuel 100 100 7242 Polk#1_SynGas2006

Syngas coal - synfuel 100 100 7242 Polk#1_VOC and SAM Retest

Syngas coal - synfuel 100 100 7242 Polk#1_VOC Retest

Syngas coal - synfuel 100 100

Page 65cem_data

facility _id tim e_period

cem_period_description

Page 66cem_data_pollutants1

facility _id tim e_period

pollutant_nam e

Page 67test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_bypass_percent

testing_bypass_percent 645 BB#1_FY2007

CS0W 1 No No 645 BB#1_FY2008

CS0W 1 No No 645 BB#1_FY2009

CS0W 1 No No 645 BB#2_29_SEP_2005

CS0W 1 No No 645 BB#2_FY2005

CS0W 1 No No 645 BB#2_FY2006

CS0W 1 No No 645 BB#2_FY2007

CS0W 1 No No 645 BB#2_FY2008

CS0W 1 No No 645 BB#3_FY2005

BB03/CS03

No No 645 BB#3_FY2006

BB03/CS03

No No 645 BB#3_FY2007

BB03/CS03

No No 645 BB#3_FY2008

BB03/CS03

No No 645 BB#3_FY2009

BB03/CS03

No No 645 BB#4_ECOTHERM

BB04/CS02

No No 645 BB#4_FY2006

BB04/CS02

No No 645 BB#4_FY2007

BB04/CS02

No No 645 BB#4_FY2008

BB04/CS02

No No 645 BB#4_FY2009

BB04/CS02

No No 7242 Polk#1_FY2007

HRSG No No 7242 Polk#1_FY2008

HRSG No No 7242 Polk#1_FY2009

HRSG No No 7242 Polk#1_OIL2005

HRSG No No 7242 Polk#1_SAM2005

HRSG No No 7242 Polk#1_SAM2006

HRSG No No 7242 Polk#1_SAM2009

HRSG No No 7242 Polk#1_SynGas2006

HRSG No No 7242 Polk#1_VOC and SAM Retest

HRSG No No 7242 Polk#1_VOC Retest

HRSG No No

Page 68test_report_sampling

fg_fraction

Page 69sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 645 BB#1_FY2007

CS0W 1 average 5/17/2009 5/17/2009 384 13.4 645 BB#1_FY2008

CS0W 1 average 3/12/2008 3/12/2008 381 13.6 645 BB#1_FY2009

CS0W 1 average 2/25/2009 2/25/2009 398 15.4 645 BB#2_29_SEP_2005

CS0W 1 average 9/29/2005 9/29/2005 273 15.2 645 BB#2_FY2005

CS0W 1 average 9/29/2005 9/29/2005 273 14.8 645 BB#2_FY2006

CS0W 1 average ######## ######## 387 11.5 645 BB#2_FY2007

CS0W 1 average ######## ######## 361 14.3 645 BB#2_FY2008

CS0W 1 average 4/2/2008 4/2/2008 380 14.8 645 BB#3_FY2005

BB03/CS03

average 2/25/2005 2/25/2005 377 7.5 645 BB#3_FY2006

BB03/CS03

average 3/8/2006 3/8/2006 392 15 645 BB#3_FY2007

BB03/CS03

average 4/5/2007 4/5/2007 369 14.8 645 BB#3_FY2008

BB03/CS03

average 8/27/2008 8/27/2008 395 16 645 BB#3_FY2009

BB03/CS03

average 6/3/2009 6/3/2009 400 15.3 645 BB#4_ECOTHERM

BB04/CS02

average 9/17/2009 9/27/2009 430 15.9 645 BB#4_FY2006

BB04/CS02

average 4/25/2006 4/25/2006 446 13.2 645 BB#4_FY2007

BB04/CS02

average 9/11/2007 9/11/2007 420 14.6 645 BB#4_FY2008

BB04/CS02

average 4/16/2008 4/16/2008 435 13.1 645 BB#4_FY2009

BB04/CS02

average 5/21/2009 5/21/2009 442 15.9 7242 Polk#1_FY2007

HRSG average 12/1/2006 12/1/2006 5.5 7242 Polk#1_FY2008

HRSG average 1/8/2008 1/8/2008 7242 Polk#1_FY2009

HRSG average ######## ######## 7242 Polk#1_OIL2005

HRSG average 8/23/2005 8/23/2005 150 7 7242 Polk#1_SAM2005

HRSG average 5/18/2005 5/18/2005 175 5.9 7242 Polk#1_SAM2006

HRSG average 2/7/2006 2/7/2006 4.4 7242 Polk#1_SAM2009

HRSG average 7242 Polk#1_SynGas2006

HRSG average 1/18/2006 1/18/2006 7242 Polk#1_VOC and SAM Retest

HRSG average 1/15/2009 1/16/2009 7242 Polk#1_VOC Retest

HRSG average 4/16/2009 4/16/2009

Page 70sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 659096 dscfm 6 13 129 652804 dscfm 6.5 13 126 556417 dscfm 7 12 128 551041 dscfm 6.4 13.4 131.2 553619 dscfm 6.3 13.3 131.6 1149146 dscfm 11.3 10.1 121 972255 dscfm 10.1 9.8 124 982268 dscfm 9 10 128 913029 dscfm 7.5 14 918166 dscfm 3.75 14.3 133 899094 dscfm 6.2 13.8 128 961500 dscfm 5 14 133 945521 dscfm 5 14 129 1630000 dscfm 7.2 11.5 131.7 1161053 dscfm 8 13 132 1074429 dscfm 8 12.2 131 1621980 dscfm 9.3 9.8 126 1550000 dscfm 5 14 130 885500 dscfm 11.6 8.8

11.3 6 861227 dscfm 10.7 7.7 904282 dscfm 11 8.7

Page 71sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value

matrix

matrix 398 12866

5B, CEM

5B, CEMS

matrix 400

matrix 442

Page 72sampling_runs

fuel_sulfur

3.45

3.3

3.15

Page 73sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 645 BB#2_29_SEP_2005

CS0W 1 average PM (Filterable) FALSE 645 BB#2_29_SEP_2005

CS0W 1 average Sulfur Dioxide (SO2) FALSE 645 BB#4_ECOTHERM

BB04/CS02

average PM (Filterable) FALSE 645 BB#4_FY2007

BB04/CS02

average Nitrogen Oxide (NOx) 47 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2007

BB04/CS02

average Sulfur Dioxide (SO2) 147 parts per million by volum e (dry) (ppmvd) FALSE 645 BB#1_FY2008

CS0W 1 average PM (Filterable) FALSE 645 BB#1_FY2008

CS0W 1 average Sulfur Dioxide (SO2) 29 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#2_FY2008

CS0W 1 average PM (Filterable) FALSE 645 BB#2_FY2008

CS0W 1 average Sulfur Dioxide (SO2) 29 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#3_FY2008

BB03/CS03

average PM (Filterable) FALSE 645 BB#3_FY2008

BB03/CS03

average Sulfur Dioxide (SO2) 58 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2008

BB04/CS02

average PM (Filterable) FALSE 645 BB#4_FY2008

BB04/CS02

average Nitrogen Oxide (NOx) 45 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2008

BB04/CS02

average Sulfur Dioxide (SO2) 131 parts per million by volum e (dry) (ppmvd) FALSE 645 BB#1_FY2009

CS0W 1 average PM (Filterable) FALSE 645 BB#1_FY2009

CS0W 1 average Sulfur Dioxide (SO2) 59 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#3_FY2009

BB03/CS03

average PM (Filterable) FALSE 645 BB#3_FY2009

BB03/CS03

average Nitrogen Oxide (NOx) FALSE 645 BB#3_FY2009

BB03/CS03

average Sulfur Dioxide (SO2) FALSE 645 BB#4_FY2009

BB04/CS02

average PM (Filterable) FALSE 645 BB#4_FY2009

BB04/CS02

average Nitrogen Oxide (NOx) 59 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2009

BB04/CS02

average Sulfur Dioxide (SO2) 128 parts per million by volum e (dry) (ppmvd) FALSE 7242 Polk#1_SAM2005

HRSG average Sulfuric Acid FALSE 7242 Polk#1_OIL2005

HRSG average Carbon Monoxide (CO) 3 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_OIL2005

HRSG average Nitrogen Oxide (NOx) 50 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_OIL2005

HRSG average Sulfur Dioxide (SO2) 9 parts per million by volum e (dry) (ppmvd) FALSE 7242 Polk#1_SynGas2006

HRSG average Carbon Monoxide (CO) 4 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_SynGas2006

HRSG average Nitrogen Oxide (NOx) 16 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_SynGas2006

HRSG average Sulfur Dioxide (SO2) 25 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_SAM2006

HRSG average Sulfuric Acid FALSE 7242 Polk#1_SAM2006

HRSG average Nitrogen Oxide (NOx) 19 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_SAM2006

HRSG average Sulfur Dioxide (SO2) 47 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2007

HRSG average Nitrogen Oxide (NOx) 14 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2007

HRSG average Sulfur Dioxide (SO2) 42 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2007

HRSG average Sulfuric Acid FALSE 7242 Polk#1_FY2007

HRSG average Carbon Monoxide (CO) 3.3 parts per million by volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2008

HRSG average Carbon Monoxide (CO) 7 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2008

HRSG average Nitrogen Oxide (NOx) 18 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2008

HRSG average Sulfur Dioxide (SO2) 41 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2009

HRSG average Carbon Monoxide (CO) 5 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2009

HRSG average VOCs FALSE 7242 Polk#1_FY2009

HRSG average Nitrogen Oxide (NOx) 20 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2009

HRSG average Sulfur Dioxide (SO2) 42 parts per million by

volum e (dry) (ppmvd) FALSE 7242 Polk#1_FY2009

HRSG average Sulfuric Acid FALSE 7242 Polk#1_VOC and SAM Retest

HRSG average VOCs FALSE 7242 Polk#1_VOC and SAM Retest

HRSG average Sulfuric Acid FALSE 7242 Polk#1_VOC and SAM Retest

HRSG average Nitrogen Oxide (NOx) FALSE 7242 Polk#1_VOC and SAM Retest

HRSG average Sulfur Dioxide (SO2) FALSE 7242 Polk#1_VOC Retest

HRSG average VOCs 0.112 parts per million by volum e (dry) (ppmvd) FALSE 645 BB#2_FY2005

CS0W 1 average PM (Filterable) FALSE 645 BB#2_FY2005

CS0W 1 average Sulfur Dioxide (SO2) FALSE

Page 74sampling_run_pollutants1

645 BB#3_FY2005

BB03/CS03

average PM (Filterable) FALSE 645 BB#3_FY2005

BB03/CS03

average Sulfur Dioxide (SO2) 121.6 parts per million by volum e (dry) (ppmvd) FALSE 645 BB#2_FY2006

CS0W 1 average PM (Filterable) FALSE 645 BB#2_FY2006

CS0W 1 average Sulfur Dioxide (SO2) 16 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#3_FY2006

BB03/CS03

average PM (Filterable) FALSE 645 BB#3_FY2006

BB03/CS03

average Sulfur Dioxide (SO2) 72 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2006

BB04/CS02

average PM (Filterable) FALSE 645 BB#4_FY2006

BB04/CS02

average Nitrogen Oxide (NOx) FALSE 645 BB#4_FY2006

BB04/CS02

average Sulfur Dioxide (SO2) FALSE 645 BB#1_FY2007

CS0W 1 average PM (Filterable) FALSE 645 BB#1_FY2007

CS0W 1 average Sulfur Dioxide (SO2) 74 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#2_FY2007

CS0W 1 average PM (Filterable) FALSE 645 BB#2_FY2007

CS0W 1 average Sulfur Dioxide (SO2) 65 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#3_FY2007

BB03/CS03

average PM (Filterable) FALSE 645 BB#3_FY2007

BB03/CS03

average Sulfur Dioxide (SO2) 40 parts per million by

volum e (dry) (ppmvd) FALSE 645 BB#4_FY2007

BB04/CS02

average PM (Filterable) FALSE 7242 Polk#1_SAM2009

HRSG average Sulfuric Acid FALSE 7242 Polk#1_SAM2009

HRSG average Nitrogen Oxide (NOx) FALSE 7242 Polk#1_SAM2009

HRSG average Sulfur Dioxide (SO2) FALSE

Page 75sampling_run_pollutants1

em ission_rate

em ission_rate_units

em ission_rate_ND

em ission_rate_MDL

em ission_factor

em ission_factor_units

em ission_factor_ND

em ission_factor_MDL

run_pollutant_comment 36.8 pound per hour (lb/hr)

FALSE FALSE combined 399.4 pound per hour (lb/hr)

FALSE FALSE From CEMS 10.6 pound per hour (lb/hr)

FALSE FALSE 304 pound per hour (lb/hr)

FALSE FALSE From CEMS 1441 pound per hour (lb/hr)

FALSE FALSE From CEMS 92 pound per hour (lb/hr)

FALSE FALSE Method 5B 311 pound per hour (lb/hr)

FALSE FALSE From CEMS 120 pound per hour (lb/hr)

FALSE FALSE Method 5B 298 pound per hour (lb/hr)

FALSE FALSE From CEMS 70 pound per hour (lb/hr)

FALSE FALSE Method 5B 494 pound per hour (lb/hr)

FALSE FALSE From CEMS 32 pound per hour (lb/hr)

FALSE FALSE Method 5B 315 pound per hour (lb/hr)

FALSE FALSE From CEMS 1312 pound per hour (lb/hr)

FALSE FALSE From CEMS 56 pound per hour (lb/hr)

FALSE FALSE Method 5B 487 pound per hour (lb/hr)

FALSE FALSE From CEMS 56 pound per hour (lb/hr)

FALSE FALSE Method 5B 343 pound per hour (lb/hr)

FALSE FALSE From CEMS 668 pound per hour (lb/hr)

FALSE FALSE From CEMS 32 pound per hour (lb/hr)

FALSE FALSE Method 5B 372 pound per hour (lb/hr)

FALSE FALSE From CEMS 1251 pound per hour (lb/hr)

FALSE FALSE From CEMS 22 pound per hour (lb/hr)

FALSE FALSE 8 pound per hour (lb/hr)

FALSE FALSE Method 10 225 pound per hour (lb/hr)

FALSE FALSE From CEM 54 pound per hour (lb/hr)

FALSE FALSE From CEM 9 pound per hour (lb/hr)

FALSE FALSE Method 10 84 pound per hour (lb/hr)

FALSE FALSE From CEMS 178 pound per hour (lb/hr)

FALSE FALSE From CEMS 31 pound per hour (lb/hr)

FALSE FALSE Method 8 99 pound per hour (lb/hr)

FALSE FALSE From CEMS 339 pound per hour (lb/hr)

FALSE FALSE From CEMS 113 pound per hour (lb/hr)

FALSE FALSE From CEMS 207 pound per hour (lb/hr)

FALSE FALSE From CEMS 34 pound per hour (lb/hr)

FALSE FALSE Method 8 12 pound per hour (lb/hr)

FALSE FALSE Method 10 16 pound per hour (lb/hr)

FALSE FALSE Method 10 102 pound per hour (lb/hr)

FALSE FALSE From CEMS 321 pound per hour (lb/hr)

FALSE FALSE From CEMS 12 pound per hour (lb/hr)

FALSE FALSE Method 10 41 pound per hour (lb/hr)

FALSE FALSE Method 18 106 pound per hour (lb/hr)

FALSE FALSE From CEMS 315 pound per hour (lb/hr)

FALSE FALSE From CEMS 42 pound per hour (lb/hr)

FALSE FALSE Method 8 34 pound per hour (lb/hr)

FALSE FALSE Method 18 47 pound per hour (lb/hr)

FALSE FALSE Method 8 100 pound per hour (lb/hr)

FALSE FALSE From CEMS 331 pound per hour (lb/hr)

FALSE FALSE From CEMS 1 pound per hour (lb/hr)

FALSE FALSE Method 18 with background subtracted 51 pound per hour (lb/hr)

FALSE FALSE Method 5B 162 pound per hour (lb/hr)

FALSE FALSE From CEMS

Page 76sampling_run_pollutants1

55.5 pound per hour (lb/hr)

FALSE FALSE Method 5B 1037.4 pound per hour (lb/hr)

FALSE FALSE From CEMS 85.28 pound per hour (lb/hr)

FALSE FALSE Method 5B 184 pound per hour (lb/hr)

FALSE FALSE From CEMS 72.8 pound per hour (lb/hr)

FALSE FALSE Method 5B 609 pound per hour (lb/hr)

FALSE FALSE From CEMS 33.6 pound per hour (lb/hr)

FALSE FALSE Method 5B 1132 pound per hour (lb/hr)

FALSE FALSE From CEMS 1434 pound per hour (lb/hr)

FALSE FALSE From CEMS 51 pound per hour (lb/hr)

FALSE FALSE Method 5B 693 pound per hour (lb/hr)

FALSE FALSE From CEMSFrom CEMS 81.2 pound per hour (lb/hr)

FALSE FALSE Method 5B 657 pound per hour (lb/hr)

FALSE FALSE From CEMS 69 pound per hour (lb/hr)

FALSE FALSE Method 5B 319 pound per hour (lb/hr)

FALSE FALSE From CEMS 33 pound per hour (lb/hr)

FALSE FALSE Method 5B 39 pound per hour (lb/hr)

FALSE FALSE Method 8 103 pound per hour (lb/hr)

FALSE FALSE From CEMS 322 pound per hour (lb/hr)

FALSE FALSE From CEMS

Page 77sampling_run_pollutants1

run_pollutant_comment

From CEMS

From CEMS From CEMS

From CEMS

From CEMS

From CEMS

From CEMS From CEMS

From CEMS

From CEMS From CEMS

From CEMS From CEMS

From CEMS From CEMS

From CEMS From CEMS From CEMS From CEMS

From CEMS From CEMS

From CEMS From CEMS

From CEMS From CEMS Method 18 with background subtracted

From CEMS

Page 78sampling_run_pollutants1

From CEMS

From CEMS

From CEMS

From CEMS From CEMS

From CEMSFrom CEMS

From CEMS

From CEMS

From CEMS From CEMS

Page 79sampling_run_fuel

facility _id report_id sampling_port_id run_id fuel_pollutant fuel_conc fuel_conc_units fuel_conc_ND

fuel_conc_MDL

Page 80sampling_run_fuel

fuel_conc_MDL

Page 81