Facility _Information

facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_ty pe

legal_address

legal_city legal_state legal_zip 4072 20860 Wi sconsin Public Service Corporation Wi sconsin Public Service Corporation

legal owner P.O. Box 19001 Green Bay WI 54307-9001 4078 20860 Wi sconsin Public Service Corporation Wi sconsin Public Service Corporation

legal owner P.O. Box 19001 Green Bay WI 54307-9001

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 Pulliam 1530 N. Bylsby Ave. Green Bay WI 54303 1530 N. Bylsby Ave. Green Bay WI 54303 We ston 2501 Morrison Ave. Rothschild WI 54474 2501 Morrison Ave. Rothschild WI 54474

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 No TRUE FALSE TRUE FALSE TRUE TRUE FALSE TRUE No TRUE TRUE TRUE FALSE TRUE TRUE TRUE TRUE

Page 3Facility _Information

ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note FALSE TRUE Notification by next business day . Report the cause and duration of the exceedance, the period of time considered necessary for correction, and measures taken to minimize emissions during the period. Yes Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co FALSE TRUE Notification by next business day . Report the cause and duration of the exceedance, the period of time considered necessary for correction, and measures taken to minimize emissions during the period. Yes Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 4Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 5Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 6Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 7Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 8Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 9Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 10Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 11Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementPulliam 3 900 900 12/31/2007Pulliam 4 900 900 12/31/2007Pulliam 5 900 900 NonePulliam 6 950 950 NonePulliam 7 1005 1000 1005 1000 None Pulliam 8 1005 1000 1005 1000 NoneUnit 8 ACI sy stem estimated to start operation in April, 2010.All co Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 12Facility _Information

Part 1 Question 15:Plant Unit Design Steam Temp. Op. Steam Temp. Design RH Temp. Op. RH Temp RetirementW eston 1 910 900 NA NA NoneW eston 2 1005 1005 1005 1005 NoneW eston 3 1005 1005 1005 1005 NoneW eston 4 1085 1085 1085 1085 NoneW eston 3 mercury control system (ACI) became operational 1/1/2010. No guarantee or feed rate were sought or provided.All concentration values for PM stack testing (filterable and condensible) found in the "Test Report Details, Test Report Samples tab, Run Details" are measured as grains per dry standard cubic foot. These units are written in the Comments box next to the test

Page 13facility _contacts

facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 4072 1 Environm ental Consultant Chris W altm an

9204332278

9206552868

cswaltman@integrysgroup.com

TRUE 4078 2 Environm ental Consultant Chris W altm an

9204332278

9206552868

cswaltma@integrysgroup.com

FALSE

Page 14facility _coal_utilized

facility _id coal_type percentage_mass percentage_btu

synfuel_type

coal_note 4072 subbituminous 100 100 4078 subbituminous 100 100

Page 15facility _oil_utilized

facility _id oil_type percentage_volume percentage_btu

other_type 4078 No.2 Fuel Oil (distillate) 100 100

Page 16facility _other_materials

facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain 4072 Boiler Cleaning Liquids (concentration based limit for HAPS, no quantity restrictions) TRUE TRUE 0 num ber/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. 4072 Controlled Substances (pounds)

TRUE TRUE 0.2 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. 4072 Oil Soaked Absorbents

TRUE FALSE 0 num ber/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. 4072 Partially

Burned Fuel TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. 4072 Petroleum Contaminated Soils (cubic yards)

TRUE FALSE 0 num ber/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. 4078 Biom ass TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. 4078 Paper Mill Sludge

TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. 4078 Partially

Burned Coal TRUE TRUE 11997 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. 4078 Tire Derived Fuels

TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. 4078 Transformer oil (< 50 ppm PCBs)

TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. 4078 Wa ste W ater Sludge

TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. 4078 Wo od W aste TRUE FALSE 0 tons/year No WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit.

Page 17facility _other_materials

rcra_explain WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit.

Page 18facility _other_materials

WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel at the facility

. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase the regulatory burden associated with burning this fuel. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit. WP SC will not com bust these materials if upcoming regulations will cause additional restrictions on unit operation or significantly increase regulatory

the regulatory

burden associated with operating the unit.

Page 19boiler_information

facility _id boiler_id boiler_ty pe boiler_other bottom_design

design_fuel heat_input ma x_heat_input MW e_capacity 4072 3 Wa ll firing - rear firing Dry Bottom coal 404.2 432 26.6 4072 4 Wa ll firing - rear firing Dry Bottom coal 404.5 444 31.3 4072 5 Wa ll firing - rear firing Dry Bottom coal 617.5 693 53.63 4072 6 Wa ll firing - rear firing Dry Bottom coal 778.4 875 73.7 4072 7 Wa ll firing - rear firing Dry Bottom coal 871.4 999 87.7 4072 8 Wa ll firing - rear firing Dry Bottom coal 1282 1510 137.9 4078 1 Wa ll firing - front firing Dry Bottom coal 849 858 63.6 4078 2 Wa ll firing - front firing Dry Bottom coal 810.1 1000 88.9 4078 3 Tangential firing Dry Bottom coal 3237.8 3423.48 365.6 4078 4 Wa ll firing - opposed firing Dry Bottom coal 4787.8 5173.07 574.5

Page 20boiler_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 24.9 86.3 74.38 675 650 300 300 FALSE 29.6 86.24 74.32 675 650 300 300 FALSE 49.83 86 82.9 1025 850 300 300 FALSE 69.6 86.1 82.36 1090 850 300 300 FALSE 82.2 88.05 84.12 1775 1450 300 300 FALSE 300 130 87.57 86.46 2150 1800 300 300 FALSE 300 60.2 86.5 86.16 1075 850 300 300 FALSE 84 87.7 88.77 1750 1450 300 300 FALSE 300 334.6 85.99 87.17 2620 2520 300 300 FALSE 300 525.4 87.36 82.87 3775 3620 300 300 FALSE 300

Page 21boiler_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 2901 14.08 N FALSE FALSE 2711 18.31 N FALSE FALSE 7166 55.59 N FALSE FALSE 6980 57.33 N FALSE FALSE 300 7208 59.78 N FALSE FALSE 300 7598 66.27 N FALSE FALSE 6998 51.71 N FALSE FALSE 300 7112 61.62 N FALSE FALSE 300 7882 68.92 Subpart D FALSE FALSE 300 6557 59.42 Subpart Da(1) FALSE

Page 22boiler_information

NOx_control

SO2_control

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

Page 23boiler_fuels

facility _id boiler_id fuel_type fuel_year percentage_massvol percentage_btu

other_type 4072 3 coal - subbituminous 2007 100 100 4072 3 other fossil fuel (specify) 2008 100 100 Unit did not operate - Retired 12/31/2007 4072 3 other fossil fuel (specify) 2009 100 100 Unit did not operate - Retired 12/31/2007 4072 4 coal - subbituminous 2007 100 100 4072 4 other fossil fuel (specify) 2008 100 100 Unit did not operate - Retired 12/31/2007 4072 4 other fossil fuel (specify) 2009 100 100 Unit did not operate - Retired 12/31/2007 4072 5 coal - subbituminous 2007 100 100 4072 5 coal - subbituminous 2008 100 100 4072 5 coal - subbituminous 2009 100 100 4072 6 coal - subbituminous 2007 100 100 4072 6 coal - subbituminous 2008 100 100 4072 6 coal - subbituminous 2009 100 100 4072 7 coal - subbituminous 2007 100 100 4072 7 coal - subbituminous 2008 100 100 4072 7 coal - subbituminous 2009 100 100 4072 8 coal - subbituminous 2007 100 100 4072 8 coal - subbituminous 2008 100 100 4072 8 coal - subbituminous 2009 100 100 4078 1 coal - subbituminous 2007 100 100 4078 1 coal - subbituminous 2008 100 100 4078 1 coal - subbituminous 2009 100 100 4078 2 coal - subbituminous 2007 100 100 4078 2 coal - subbituminous 2008 100 100 4078 2 coal - subbituminous 2009 100 100 4078 3 coal - subbituminous 2007 100 100 4078 3 coal - subbituminous 2008 100 100 4078 3 coal - subbituminous 2009 100 100 4078 4 coal - subbituminous 2008 100 100 4078 4 coal - subbituminous 2009 100 100 4078 4 other fossil fuel (specify) 2007 100 100 New unit - did not operate until 2008.

Page 24boiler_fuels

Unit did not operate - Retired 12/31/2007 Unit did not operate - Retired 12/31/2007

Unit did not operate - Retired 12/31/2007 Unit did not operate - Retired 12/31/2007

New unit - did not operate until 2008.

Page 25boiler_control_NOx

facility _id boiler_id NOx_type NOx_other NOx_online 4072 5 Low NOx Burner 6/1/2010 4072 5 Overfire Air 6/1/2010 4072 6 Low NOx Burner 6/1/2009 4072 6 Overfire Air 6/1/2009 4072 7 Low NOx Burner 6/1/1994 4072 7 Overfire Air 6/1/2009 4072 8 Low NOx Burner 2/1/1994 4072 8 Overfire Air 11/1/2009 4078 1 Low NOx Burner 1/1/2009 4078 1 Overfire Air 1/1/2009 4078 2 Low NOx Burner 1/1/2009 4078 2 Overfire Air 3/1/2009 4078 3 Low NOx Burner 10/1/2009 4078 3 Overfire Air 10/1/2009 4078 4 Low NOx Burner 7/1/2008 4078 4 Overfire Air 7/1/2008

Page 26boiler_control_SO2

facility _id boiler_id SO2_type SO2_other SO2_online 4072 3 Low Sulfur Coal 1/1/1992 4072 4 Low Sulfur Coal 1/1/1992 4072 5 Low Sulfur Coal 1/1/1992 4072 6 Low Sulfur Coal 1/1/1992 4072 7 Low Sulfur Coal 1/1/1992 4072 8 Low Sulfur Coal 1/1/1992 4078 1 Low Sulfur Coal 1/1/1991 4078 2 Low Sulfur Coal 1/1/1991 4078 3 Low Sulfur Coal 12/1/1981 4078 4 Low Sulfur Coal 7/1/2008

Page 27boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online 4072 3 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 6/1/1994 4072 4 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 2/1/1994 4072 5 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 1/1/1988 4072 6 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 9/1/1988 4072 7 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 9/1/1988 4072 8 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 1/1/1988 4078 1 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 1/1/1990 4078 2 Flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other) 1/1/1990

Page 28facility _units

facility _id unit_id 4072 3 4072 4 4072 5 4072 6 4072 7 4072 8 4078 1 4078 2 4078 3 4078 4

Page 29unit_boilers

facility _id unit_id boiler_id 4072 3 3 4072 4 4 4072 5 5 4072 6 6 4072 7 7 4072 8 8 4078 1 1 4078 2 2 4078 3 3 4078 4 4

Page 30facility _controls

facility _id control_id control_group control_type

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 4072 P3 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 1/1/1954 4072 P4 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 1/1/1955 4072 P5 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 1/1/1953 4072 P6 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 11/1/1951 4072 P7 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 11/1/1958 4072 P8 ACI Other control Activated carbon injection FALSE 4072 P8 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 12/1/1964 4078 W1 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 1/1/1971 4078 W2 ESP PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 1/1/1972 4078 W3 BH PM control Fabric Filter, pulse FALSE 5/1/2001 4078 W3 HG Other control Activated carbon injection FALSE 4078 W4 BH PM control Fabric Filter, pulse FALSE 7/1/2008 4078 W4 HG Other control Activated carbon injection FALSE 7/1/2008 4078 W4 SCR NOx control Selective Cataly

tic Reduction FALSE 7/1/2008 Am mo nia 4078 W4 SDA SO2 control Spray dryer type FALSE 7/1/2008

Page 31facility _controls

reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive

19 Lim e NO

Page 32facility _sampling_ports

facility _id sampling_port_id 4072 CS34 Port 4072 CS56 Port 4072 P7 Port 4072 P8 Port 4078 W1 Port 4078 W2 Port 4078 W3Port 4078 W4 Port

Page 33facility _stacks

facility _id stack_id stack_height stack_diameter

sack_gas_velocity 4072 Common Stack 3-4 377 11.5 4072 Common Stack 5-6 377 15 4072 Stack 7 377 11 4072 Stack 8 377 15.5 4078 W1 Stack 242 11.88 4078 W2 Stack 242 11.88 4078 W3Stack 498 16 4078 W4 Stack 500 19.51

Page 34configurations

facility _id configuration_id 4072 3 4072 4 4072 5 4072 6 4072 7 4072 8 4078 W1 4078 W2 4078 W3 4078 W4

Page 35configuration_components

facility _id configuration_id

component_id

order component_ty pe port_near 4072 3 3 1 Unit 4072 3 Common Stack 3-4 4 Stack 4072 3 CS34 Port 3 Sam pling Port next 4072 3 P3 ESP 2 PM control 4072 4 4 1 Unit 4072 4 Common Stack 3-4 4 Stack 4072 4 CS34 Port 3 Sam pling Port next 4072 4 P4 ESP 2 PM control 4072 5 5 1 Unit 4072 5 Common Stack 5-6 4 Stack 4072 5 CS56 Port 3 Sam pling Port next 4072 5 P5 ESP 2 PM control 4072 6 6 1 Unit 4072 6 Common Stack 5-6 4 Stack 4072 6 CS56 Port 3 Sam pling Port next 4072 6 P6 ESP 2 PM control 4072 7 7 1 Unit 4072 7 P7 ESP 2 PM control 4072 7 P7 Port 3 Sam pling Port next 4072 7 Stack 7 4 Stack 4072 8 8 1 Unit 4072 8 P8 ACI 2 Other control 4072 8 P8 ESP 3 PM control 4072 8 P8 Port 4 Sam pling Port next 4072 8 Stack 8 5 Stack 4078 W1 1 1 Unit 4078 W1 W1 Port 3 Sam pling Port next 4078 W1 W1 Stack 4 Stack 4078 W1 W1 ESP 2 PM control 4078 W2 2 1 Unit 4078 W2 W2 Port 3 Sam pling Port next 4078 W2 W2 Stack 4 Stack 4078 W2 W2 ESP 2 PM control 4078 W3 3 1 Unit 4078 W3 W3Port 4 Sam pling Port next 4078 W3 W3Stack 5 Stack 4078 W3 W3 BH 2 PM control 4078 W3 W3 HG 3 Other control 4078 W4 4 1 Unit 4078 W4 W4 Port 6 Sam pling Port next 4078 W4 W4 Stack 7 Stack 4078 W4 W4 BH 5 PM control 4078 W4 W4 HG 3 Other control 4078 W4 W4 SCR 2 NOx control 4078 W4 W4 SDA 4 SO2 control

Page 36configuration_pollutants1

facility _id configuration_id

pollutant_nam e

permit_ty pe_1

em lim it_1 em lim it_units_1 avg_period_1

em lim it_2 em lim it_units_2 4072 3 PM (Filterable) Fderal - Title V Operating Permit 4072 4 PM (Filterable) Fderal - Title V Operating Permit 4072 5 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 69.3 pound per hour (lb/hr) 4072 5 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

3.31 pound per million British Thermal Unit (lb/MMBtu) 4072 5 Total Mercury (Hgt) 350 4072 5 Carbon Monoxide (CO) State - Permit to Contruct

0.29 pound per million British Thermal Unit (lb/MMBtu) 5.1 4072 6 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 87.5 pound per hour (lb/hr) 4072 6 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

3.31 pound per million British Thermal Unit (lb/MMBtu) 4072 6 Total Mercury (Hgt) 350 4072 6 Carbon Monoxide (CO) State - Permit to Contruct

0.29 pound per million British Thermal Unit (lb/MMBtu) 4072 7 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 99.9 pound per hour (lb/hr) 4072 7 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

3.31 pound per million British Thermal Unit (lb/MMBtu) 4072 7 Total Mercury (Hgt) 350 4072 7 Carbon Monoxide (CO) State - Permit to Contruct

0.29 pound per million British Thermal Unit (lb/MMBtu) 7.3 4072 8 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 151 pound per hour (lb/hr) 4072 8 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

3.31 pound per million British Thermal Unit (lb/MMBtu) 4072 8 Total Mercury (Hgt) 350 4072 8 Carbon Monoxide (CO) State - Permit to Contruct

0.29 pound per million British Thermal Unit (lb/MMBtu) 11.1 4078 W1 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 85.8 pound per hour (lb/hr) 4078 W1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

763.9 pound per hour (lb/hr) 4078 W1 Carbon Monoxide (CO) Federal - Title V Operating Permit

0.29 pound per million British Thermal Unit (lb/MMBtu) 4.8 4078 W1 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

1079.5 pound per hour (lb/hr) 4078 W2 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 100 pound per hour (lb/hr) 4078 W2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

890 pound per hour (lb/hr) 4078 W2 Carbon Monoxide (CO) Federal - Title V Operating Permit

0.29 pound per million British Thermal Unit (lb/MMBtu) 4078 W2 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

1258 pound per hour (lb/hr) 4078 W3 PM (Filterable) Fderal - Title V Operating Permit

0.1 pound per million British Thermal Unit (lb/MMBtu) 342.3 pound per hour (lb/hr) 4078 W3 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 4108.2 pound per hour (lb/hr) 4078 W3 Carbon Monoxide (CO) Federal - Title V Operating Permit 4078 W3 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

3 hours 2396.4 pound per hour (lb/hr) 4078 W4 PM (Filterable) State - Permit to Contruct

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

3 hours 103.52 pound per hour (lb/hr) 4078 W4 PM10 (Filterable) State - Permit to Contruct

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

3 hours 4078 W4 Sulfur Dioxide (SO2) State - Permit to Contruct

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

30 days 0.09 pound per million British Thermal Unit (lb/MMBtu) 4078 W4 Carbon Monoxide (CO) State - Permit to Contruct

0.15 pound per million British Thermal Unit (lb/MMBtu) 4078 W4 Nitrogen Oxide (NOx) State - Permit to Contruct

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

30 days 4078 W4 Lead (Pb) State - Permit to Contruct 0.13 pound per hour (lb/hr) 4078 W4 Total Mercury (Hgt) State - Permit to Contruct

1.7 pound per trillion British Thermal Unit (lb/1012Btu) 4078 W4 Hydrogen Fluoride (HF) State - Permit to Contruct

0.000217 pound per million British Thermal Unit (lb/MMBtu) 1.12 pound per hour (lb/hr) 4078 W4 Beryllium (Be) State - Permit to Contruct

1.3 pound per trillion British Thermal Unit (lb/1012Btu) 4078 W4 Hydrogen Chloride (HCl) State - Permit to Contruct

10.94 pound per hour (lb/hr)

24 hours 4078 W4 Total Hydrocarbons (THC) (as Methane) State - Permit to Contruct

0.0036 pound per million British Thermal Unit (lb/MMBtu) 81.6 4078 W1 Total Mercury (Hgt) 350 4078 W2 Total Mercury (Hgt) 350 4078 W3 Total Mercury (Hgt) 350

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eq_recordkeeping Unit 3 retired 12/31/2007. No longer included in the Title V Operating Permit. No None - Unit retired 12/31/2007. None - Unit retired 12/31/2007. Unit 3 retired 12/31/2007. No longer included in the Title V Operating Permit. No None - Unit retired 12/31/2007. None - Unit retired 12/31/2007. pound per hour (lb/hr) No averaging periods Method 5 and 202 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid. The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP):(a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; and(e) the sparking rate in sparks per minute. The parameters identified above shall be used as performance indicators for the ESP. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing bythe Department. The plan must include actions to be taken if parameters are measured outside the Plan range. Unless an alternate method is approved by the Department in writing, periodic internal inspections of each electrostatic precipit The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp pound per million British Thermal Unit (lb/MMBtu) No averaging periods No The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: (a) complete a minimum of one cycle of sampling, analyzing, and data recording for each successive fifteen-minute period. (b) the values recorded shall be averaged hourly , and (c) hourly averages shall be computed from four data points equally spaced over each one hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least two data points separated by a minimum of fifteen minutes.(d) for periods of monitor downtime follow the QA/QC Plan. The permittee shall follow a Quality Assurance and Quality Control Plan as approved by the Department for the continuous emission monitor. 350 pounds per year emission limit as a fleet-wide total (not a unit-specific emission limit) No The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova 0.29 lb/m mB tu with a 12-m onth average and a 5.1 ton per day mass limit. No 250 ppm or 100 ppm + baseline CO concentration. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code.The continuous carbon monoxide monitor required shall perform sampling, analyzing, and data recording as follows:(a) complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period.(b) the values recorded shall be averaged hourly .(c) hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition. The quality

control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM. pound per hour (lb/hr) No averaging period. Methods 5 and 202 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid. The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP):(a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; and(e) the sparking rate in sparks per minute. The parameters identified above shall be used as performance indicators for the ESP. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing bythe Department. The plan must include actions to be taken if parameters are measured outside the Plan range. Unless an alternate method is approved by the Department in writing, periodic internal inspections of each electrostatic precipit The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp pound per million British Thermal Unit (lb/MMBtu) No averaging period. No The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: (a) complete a minimum of one cycle of sampling, analyzing, and data recording for each successive fifteen-minute period. (b) the values recorded shall be averaged hourly , and (c) hourly averages shall be computed from four data points equally spaced over each one hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least two data points separated by a minimum of fifteen minutes.(d) for periods of monitor downtime follow the QA/QC Plan. The permittee shall follow a Quality Assurance and Quality Control Plan as approved by the Department for the continuous emission monitor. 350 pounds per yar emission limit as a fleet-wide total (not a unit-specific emission limit) No The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova None. pound per million British Thermal Unit (lb/MMBtu) 0.29 lb/m mB tu with a 12-m onth average and a 6.4 ton per day mass limit. No 250 ppm or 100 ppm + baseline CO concentration. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code.The continuous carbon monoxide monitor required shall perform sampling, analyzing, and data recording as follows:(a) complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period.(b) the values recorded shall be averaged hourly .(c) hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition. The quality

control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM. pound per hour (lb/hr) No averaging period. Methods 5 and 202 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid. The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP):(a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; and(e) the sparking rate in sparks per minute. The parameters identified above shall be used as performance indicators for the ESP. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing bythe Department. The plan must include actions to be taken if parameters are measured outside the Plan range. Unless an alternate method is approved by the Department in writing, periodic internal inspections of each electrostatic precipit The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp pound per million British Thermal Unit (lb/MMBtu) No averaging period. No The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: (a) complete a minimum of one cycle of sampling, analyzing, and data recording for each successive fifteen-minute period. (b) the values recorded shall be averaged hourly , and (c) hourly averages shall be computed from four data points equally spaced over each one hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least two data points separated by a minimum of fifteen minutes.(d) for periods of monitor downtime follow the QA/QC Plan. The permittee shall follow a Quality Assurance and Quality Control Plan as approved by the Department for the continuous emission monitor. State rule: 350 pounds per yar emission limit as a fleet-wide total (not a unit-specific emission limit) No The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova 0.29 lb/m mB tu with a 12-m onth average and a 7.3 ton per day mass limit. No 250 ppm or 100 ppm + baseline CO concentration. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code.The continuous carbon monoxide monitor required shall perform sampling, analyzing, and data recording as follows:(a) complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period.(b) the values recorded shall be averaged hourly .(c) hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition. The quality

control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM. pound per hour (lb/hr) No averaging period. Methods 5 and 202 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid. The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP):(a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; and(e) the sparking rate in sparks per minute. The parameters identified above shall be used as performance indicators for the ESP. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing bythe Department. The plan must include actions to be taken if parameters are measured outside the Plan range. Unless an alternate method is approved by the Department in writing, periodic internal inspections of each electrostatic precipit The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp pound per million British Thermal Unit (lb/MMBtu) No averaging period. No The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: (a) complete a minimum of one cycle of sampling, analyzing, and data recording for each successive fifteen-minute period. (b) the values recorded shall be averaged hourly , and (c) hourly averages shall be computed from four data points equally spaced over each one hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least two data points separated by a minimum of fifteen minutes.(d) for periods of monitor downtime follow the QA/QC Plan. The permittee shall follow a Quality Assurance and Quality Control Plan as approved by the Department for the continuous emission monitor. State rule: 350 pounds per yar emission limit as a fleet-wide total (not a unit-specific emission limit) 2.49 pound per trillion British Thermal Unit (lb/1012Btu)

No 2.49 LB/TBTU at stack if Hg content of coal is less than 8.3 LB/TBTU or 70% removal (coal inlet to stack outlet) if Hg content of coal is greater than 8.3 LB/TBTU The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova 0.29 lb/m mB tu with a 12-m onth average and a 11.1 ton per day mass limit. No 250 ppm or 100 ppm + baseline CO concentration. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code.The continuous carbon monoxide monitor required shall perform sampling, analyzing, and data recording as follows:(a) complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period.(b) the values recorded shall be averaged hourly .(c) hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition. The quality

control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM. pound per hour (lb/hr) No averaging period 5/OTM 28 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid.The permittee shall repeat the compliance emissions test prior to firing on a continuous basis wood waste, refuse waste, waste water sludge and tire derived fuels.The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP): (a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; (e) the sparking rate in sparks per minute.The parameters identified shall be used to correlate the relationship between normal performance and the manufacturer's performan The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha No averaging period. 1029.6 lbs/hr when W 2 @ 8.9 lbs/hr 6.6 lbs/hr when W 2 @ 1200 lbs/hr 763.9 lbs/hr when W 2 @ 890 lbs/hr No The permittee shall calibrate, maintain and operate a continuous monitoring system. The permittee shall calibrate, maintain and operate the continuous emission monitor required in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period. The values recorded shall be averaged hourly . Hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consis of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor. 0.29 lbs/mmBtu 12 month ave.; 4.8 Tons/day No 250 PPM or 100 PPM + baseline The permittee shall install, calibrate, maintain and operate a continuous monitoring system that meets the performance specifications of s. NR 439.09(4), W is.Adm. Code, for the measurement of carbon monoxide emissions from stack S01. The installation of the CEM and initial calibration shall be completed within 180 days of the startup of the boiler following installation of the overfire air system.The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition I.A.5.a.(3). The quality control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM.The continuous carbon monoxide monitor shall perform sampling, analyzing, and The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition I.A.5.a.(3). The quality control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM No averaging period. 0.235 pound per million British Thermal Unit (lb/MMBtu) No Nox = 0.235 LB/MMBTU @ 175 ppm CO OR 0.22 LB/MMBTU @ 250 ppm CO The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. pound per hour (lb/hr) No averaging period. 5/OTM 28 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid.The permittee shall repeat the compliance emissions test prior to firing on a continuous basis wood waste, refuse waste, waste water sludge and tire derived fuels.The permittee shall monitor the following operational parameters for each electrostatic precipitator (ESP): (a) the primary voltage in volts; (b) the secondary voltage in volts; (c) the primary current in amps; (d) the secondary current in amps; (e) the sparking rate in sparks per minute.The parameters identified shall be used to correlate the relationship between normal performance and the manufacturer's perform The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha No averaging period. 1200 lbs/hr when W 1 @ 6.6 lbs/hr 8.9 lbs/hr when W 1 @ 1029.6 lbs/hr 890 lbs/hr when W 1 @ 763 lbs/hr. No The permittee shall calibrate, maintain and operate a continuous monitoring system. The permittee shall calibrate, maintain and operate the continuous emission monitor required in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor shall perform sampling, analyzing, and data recording as follows: complete one cycle of sampling, analyzing, and data recording for each successive 15-minute period. The values recorded shall be averaged hourly . Hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrations, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consis of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor. pound per million British Thermal Unit (lb/MMBtu) 0.29 lbs/mmBtu 12 month ave.; 5.6 Tons/day No 250 PPM or 100 PPM + baseline The permittee shall install, calibrate, maintain and operate a continuous monitoring system that meets the performance specifications of s. NR 439.09(4), W is. Adm. Code, for the measurement of carbon monoxide emissions from stack S01. The installation of the CEM and initial calibration shall be completed within 180 days of the startup of the boiler following installation of the overfire air system.The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition I.A.5.a.(3). The quality control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM.The continuous carbon monoxide monitor shall perform sampling, analyzing, and d The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor required by condition I.A.5.a.(3). The quality control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM No averaging period. 0.235 pound per million British Thermal Unit (lb/MMBtu) No Nox = 0.235 LB/MMBTU @ 175 ppm CO OR 0.22 LB/MMBTU @ 250 ppm CO The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. pound per hour (lb/hr) No averaging period. 5/OTM 28 No The permittee shall perform compliance emission testing of particulate matter emissions from this boiler to demonstrate compliance with the particulate matter emission limit. Testing shall be conducted every 24 months as long as the permit remains valid."The permittee shall monitor the following operational parameters for each baghouse: pressure drop range.The parameters identified in I.C1.b.(2) shall be used to correlate the relationship between normal performance and the manufacturer's performance indicators for the baghouse. The permittee shall define normal performance in its Malfunction, Prevention and Abatement Plan.The permittee shall perform periodic internal inspections of the baghouse to ensure that the control equipment is operating properly . The time interval between inspections may not exceed eighteen (18) months.The permittee shall perform an elemental metal analysis of the RPM partially burned coal and W ausau – Mosinee Mill (or other ash as approved by March 1st of every

year tha The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh 3 hours No The permittee shall calibrate, maintain and operate a continuous monitoring system for the measurement of sulfur dioxide from each stack. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous sulfur dioxide monitor required shall perform sampling, analyzing, and data recording as follows: complete one cycle of sampling, analyzing, and data recording for each successive 15 minute period. The values recorded shall be average hourly . Hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrationis, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor. 350 ppmvd (3% O2) (rolling 24 hr ave); 250 ppmvd (3% O2) (12 month ave.) No 200 PPM corr. 3% O2 The permittee shall install, calibrate, maintain and operate a continuous monitoring system that meets the performance specifications of s. NR 439.09(4), W is. Adm. Code, for the measurement of carbon monoxide emissions from stack S03. The installation of the CEM and initial calibration shall be completed within 180 days of the startup of the boiler following installation of the overfire air system The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in s. NR 439.09(4), W is. Adm. Code.The continuous carbon monoxide monitor required shall perform sampling, analyzing, and data recording as follows: complete one cycle of sampling, analyzing, and data recording for each successive 15 minute period. The values recorded shall be average hourly . Hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrationis, quality assurance or maintenance activities are The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor. The quality control and quality

assurance plan shall be submitted to the Department for review and possible changes within 30 days of completion of the initial calibration tests on the CEM. 3 hours 0.12 pound per million British Thermal Unit (lb/MMBtu) No NOx = 0.11 or 0.12 LB/MMBTU (Coal dependent) The permittee shall calibrate, maintain and operate a continuous monitoring system for the measurement of nitrogen oxides from each stack. The permittee shall calibrate, maintain and operate the continuous emission monitor in accordance with the performance specifications in 40 CFR Part 75, Appendices A to I.The continuous nitrogen oxides monitor required shall perform sampling, analyzing, and data recording as follows: complete one cycle of sampling, analyzing, and data recording for each successive 15 minute period. The values recorded shall be average hourly . Hourly averages shall be computed from 4 data points equally spaced over each 1 hour period, except during periods when calibrationis, quality assurance or maintenance activities are being performed. During these periods, a valid hour shall consist of at least 2 data points separated by a minimum of 15 minutes. The permittee shall follow a quality control and quality

assurance plan as approved by the Department for the continuous emission monitor. 3 hours 5/OTM 28 0.18 pound per million British Thermal Unit (lb/MMBtu) No 0.018 LB/MMBTU TOTAL  0.015 LB/MMBTU FRONT HALF ONLY Perform the compliance emission tests every 24 months within 60 days from the date of the last stack test for as long as the permit remains validRecord the pressure drop across the fabric filter baghouse system once for every 8 hours of operation.Continuously monitor the operating pressure drop across the fabric filter system and sound an audible alarm whenever the operating pressure drop is below the minimum pressure drop.Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Keep and m aintain on site technical drawings, blueprints or equivalent records of the physical stack parameters.Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results.Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code.Keep appropriate records on the manufacturer's design specifications for the natural gas burners to demonstrate compliance with permit conditions. 201A 0.18 pound per million British Thermal Unit (lb/MMBtu) No 0.018 LB/MMBTU TOTAL  0.015 LB/MMBTU FRONT HALF ONLY Perform the compliance emission tests every 24 months within 60 days from the date of the last stack test for as long as the permit remains validRecord the pressure drop across the fabric filter baghouse system once for every 8 hours of operation.Continuously monitor the operating pressure drop across the fabric filter system and sound an audible alarm whenever the operating pressure drop is below the minimum pressure drop.Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Keep and m aintain on site technical drawings, blueprints or equivalent records of the physical stack parameters.Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results.Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code.Keep appropriate records on the manufacturer's design specifications for the natural gas burners to demonstrate compliance with permit conditions. pound per million British Thermal Unit (lb/MMBtu) 0.10 lbs/mmBtu 30 day ave 0.09 lbs/mmBtu 12 mo. Ave 90% control 30 day ave 621 lbs/hr 3 hr ave 589 lbs/hr 24 hr ave  Sulfur control system maintenance: - 3491.8 lbs/hr 3 hr ave & 1508.9 lbs/hr 24 hr ave. 0.08 pound per million British Thermal Unit (lb/MMBtu)

No Install, calibrate, maintain and operate a continuous emission monitoring system, and record the output of the system for measuring the sulfur dioxide and oxygen or carbon dioxide content of the flue gases at each location where sulfur dioxide emissions are monitored.Continuous emissions monitoring systems shall be installed and operated in accordance with 40 CFR Part 75, NR 440.20(7)(b), W is Admin Code and s. NR 439.06(2) W is Admin Code.Continuous SO2 emission monitors located at the inlet and outlet to the SO2 control device shall be used to measure the control efficiency of the SO2 control device.Use continuous emission monitoring methods and procedures under NR 440.20(7)(b) W is. Admin Code and NR 439.09 W is Admin Code to comply with the NSPS m onitoring requirements.Monitor and maintain the flow rate of the aqueous lime/recycled ash slurry to the FGD system and the pressure dorp across the srubber within the range specified.Demonstrate compliance with the coal sulfur dioxide limit by ut Comply with the NSPS com pliance determination procedures and methods per NR 440.20(6)and(8) W is.Admin.Code.Keep appropriate records to comply with perm it conditions.Keep appropriate records (date the atomizer were changed, the hours the boiler operated since the last atomizer changed) to show compliance with permit conditions. pound per million British Thermal Unit (lb/MMBtu) 0.15 lbs/mmBtu (daily ave.) 3399 tons (12 month ave) 0.12 pound per million British Thermal Unit (lb/MMBtu)

No Perform the compliance emission tests every 60 months within 60 days from the date of the last stack test as long as the permit remains valid.Install and operate continuous emissions monitoring systems (CEMS) for CO and oxygen or CO2 within 60 days after initial start up of the boiler. The CEMS shall be calibrated within 90 days after initial start up of the boiler. Continuous emissions monitoring systems shall be installed and operated in accordance with 40 CFR Part 60 Appendix B and NR 439.06 and (4) W is Admin Code.During operation, the facility will calculate or continuously monitor and record the unit heat input and furnace outlet temperature, oF operating parameters on an hourly basis.During operation, the facility will calculate or continuously monitor and record the unit heat input and secondary air flow , primary

air flow, fuel flow, and residence time operating parameters on an hourly basis.During the initial performance testing, the permittee shall perform simultaneous monitoring of Keep appropriate records to show that the boiler is equipped with low NOX burners.Keep records to show that they did not exceed the permitted emission limit. 0.06 lbs/mmBtu (30 day ave) 0.06 lbs/mmBtu (12 mo ave) 0.05 pound per million British Thermal Unit (lb/MMBtu)

No Install and operate continuous emissions monitoring systems (CEMS) for NOX and carbon dioxide or oxygen within 60 days after initial start up of the boiler. The CEMS shall be calibrated within 90 days after initial start up of the boiler. Continuous emissions monitoring systems shall be installed and operated in accordance with 40 CFR Part 75, NR 440.20(7)(d) W is Admin Code and NR 439.06(6)(b) W is Admin Code requirements.Perform the compliance emission tests required every 60 months within 60 days from the date of the last stack test as long as the permit remains valid.During operation, the facility will calculate or continuously monitor and record the unit heat input and furnace outlet temperature, including SCR inlet temperature, oF, operating parameters on an hourly basis.During operation, the facility will calculate or continuously monitor and record the unit heat input and secondary air flow operating parameters on an hourly basis.During operation, the facility will calculate or continuo Keep appropriate records of the strip chart, round chart or data acquisition (DAS) system/electronic data storage continuously .Com ply with NSPS com pliance determination procedures and methods per NR 440.20(6) W is Admin Code.Keep appropriate records to show that the boiler is equipped with low NOX burners. No averaging period. No Perform the compliance emission tests every 60 months from the date of the last stack test as long as the permit remains valid.Record the pressure drop across the fabric filter baghouse system once for every 8 hours of operation. Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results. pound per trillion British Thermal Unit (lb/1012Btu) 12 month averaging period. 1.5 pound per trillion British Thermal Unit (lb/1012Btu) No Perform 4 stack tests within 18 months of the initial operation the first of which shall be performed at the beginning of the initial operation period and every 6 months until the initial operation period has been completed. After the initial operating phase the stack testing shall be performed biannually .Perform the compliance emission test every 60 months form the date of the last stack test as long as the permit remains valid.Determine mercury emission through coal sampling and analysis. The permittee shall monitor monthly average mercury

content and higher heating value in the coal.Record the pressure drop across the fabric filter baghouse system once for every 8 hours of operation. Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the action, initials of inspector and the results.Keep a continuous record of the sorbent feed rate in lb per Mcf of exhaust gas.Keep a copy of the final test report for each Hg compliance test. pound per hour (lb/hr) No averaging period. Permitted as total Fluorides, not just Hydrogen Fluoride. No Compliance demonstration for fabric filter baghouse system and the dry FGD system shall be used as compliance demonstration techniques for fluoride emissions as well. Compliance demonstration for fabric filter baghouse system and the dry FGD system shall be used as compliance demonstration techniques for fluoride emissions as well. pound per trillion British Thermal Unit (lb/1012Btu) No averaging period. No Compliance demonstration identified earlier in this permit for fabric filter baghouse system and the dry FGD system shall be used as compliance demonstration techniques for bery llium emissions as well.Perform the compliance emission tests every 60 months from the date of the last stack test as long as the permit remains valid.Monitor bery llium emissions through coal sampling and analysis. The permittee shall monitor monthly average beryllium content and higher heating value in the coal.Record the pressure drop across the fabric filter baghouse system once for every 8 hours of operation Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results. No Initial com pliance emissions test shall be conducted within 180 days after the start of operation of the boiler.The permittee shall perform the compliance emission tests every 60 months from the date of the last stack test as long as the permit remains valid.The flow rate of aqueous lime/recycled ash slurry to the FGD system and the pressure drop across the scrubber shall be periodically monitored and maintained withinthe range specified in the permit.Instrumentation to monitor the aqueous lime/recycled ash slurry to the dry

flue gas desulfurization system and pressure drop across the the FGD shall be installed and operated properly

. None .0036 lb/m mB TU daily

average81.6 tons 12 month rolling average Initial com pliance emission test shall be conducted within 180 days after the start of operation of the boiler to show compliance with the emission limitation.VOC emissions shall be controlled using low Nox burners and good combustion practices to meet BACT limits. The permittee shall demonstrate complinace with the volatile organic compound emission limit as follows: VOC emission shal be calculated on each calendar day . The permittee shall calculate an hourly average emission rate based on measured data using CO CEMS required in I.A.5.b.(4) by combining the CO concentration and diluent concentration measurement concistent with the procedures specified in 40 CFR Part 75 Appendix F in the following equation = VOC actual = VOC limit x (CO actual/CO limit) During operation, the facility will calculate or continuously monitor and record the unit heat input and the following operating parameters on an hourly basis a. Furnace outlet temperature, b. secondary air flow, primary

air flow, fule flow rate, Keep appropriate records to show that the boiler is equipped with low NOX burners.The permittee shall monitor the temperature of the flue gas entering the SCR and keep records of the flue gas temperature entering the SCR. 350 pounds per year emission limit as a fleet-wide total (not a unit-specific emission limit) The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova 350 pounds per year emission limit as a fleet-wide total (not a unit-specific emission limit) The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova 350 pounds per year emission limit as a fleet-wide total (not a unit-specific emission limit) The source performance test shall be conducted according to Method 101A in Appendix B of 40 CFR part 61, incorporated by reference in s. NR 484.04(23); Method 29 in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20m); Method 30A or 30B in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 484.04(20s) and (20t) respectively ; or ASTM D6784-02, incorporated by reference in s. NR 484.10(55x). 2. A sample of the fuel burned during the test shall be analy zed for mercury

content, using ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department. During each of the 3 runs of the performance test, a separate sample of the fuel being burned during the run shall be collected and analy zed. 3. During the source performance testing, the consumption of fuel shall be monitored and recorded. 4. The major utility shall submit to the Department the information obtained in subds. 1. to 3. and the calculations for the percent remova

Page 38configuration_pollutants1

req_reporting None - Unit retired 12/31/2007. None - Unit retired 12/31/2007. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. Subm it test results to W isconsin DNR. The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Subm it quarterly

reports to the DNR on the information required in this permit for each train of coal received during the calendar quarter.Comply with NSPS reporting requirements per NR 440.20(9) W is Admin Code Continuous emission monitoring methods and procedures shall comply with the requirem ents of NR 439.09 W is Admin Code Comply with NSPS com pliance determination procedures and methods per NR 440.20(6) W is Admin Code.Comply with the NSPS reporting requirements per NR 440.20(9) W is Admin Code. Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results. The data obtained from the monthly coal sampling and analysis shall be correllated with the results of the latest emission compliance test for the purpose of calculating mercury emission rate. Submit the results of the compliance testing to the DNR and the DNR will review the test results and adjust the emissions limit to more accurate reduction levels for mercury when the operation permit is issued. Compliance demonstration for fabric filter baghouse system and the dry FGD system shall be used as compliance demonstration techniques for fluoride emissions as well. The data obtained from the monthly coal sampling and analysis shall be correlated with the results of the latest emission compliance test for the purpose of calculating bery llium emission rate. None Keep appropriate records to show that the boiler is equipped with low NOX burners.The permittee shall monitor the temperature of the flue gas entering the SCR and keep records of the flue gas temperature entering the SCR.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 39configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter. The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee will demonstrate compliance with the applicable NOx hourly emission limit by

using fuel consumption records and AP-42 emission factor. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. The permittee shall submit quarterly excess emission reports to the Department within 30 days following the end of each calendar quarter. Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Comply with NSPS m onitoring, recordkeeping and reporting requirements per NR 440.20(9), W is. Admin. Code Subm it quarterly

reports to the DNR on the information required in this permit for each train of coal received during the calendar quarter.Comply with NSPS reporting requirements per NR 440.20(9) W is Admin Code Continuous emission monitoring methods and procedures shall comply with the requirem ents of NR 439.09 W is Admin Code Comply with NSPS com pliance determination procedures and methods per NR 440.20(6) W is Admin Code.Comply with the NSPS reporting requirements per NR 440.20(9) W is Admin Code. Keep records of all inspections, checks and any maintenance or repairs performed on the fabric filter baghouse system, containing the date of the actions, initials of inspector, and the results. The data obtained from the monthly coal sampling and analysis shall be correllated with the results of the latest emission compliance test for the purpose of calculating mercury emission rate. Submit the results of the compliance testing to the DNR and the DNR will review the test results and adjust the emissions limit to more accurate reduction levels for mercury when the operation permit is issued. Compliance demonstration for fabric filter baghouse system and the dry FGD system shall be used as compliance demonstration techniques for fluoride emissions as well. The data obtained from the monthly coal sampling and analysis shall be correlated with the results of the latest emission compliance test for the purpose of calculating bery llium emission rate.

Keep appropriate records to show that the boiler is equipped with low NOX burners.The permittee shall monitor the temperature of the flue gas entering the SCR and keep records of the flue gas temperature entering the SCR.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 40configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

Subm it quarterly

reports to the DNR on the information required in this permit for each train of coal received during the calendar quarter.Comply with NSPS reporting requirements per NR 440.20(9) W is Admin Code

The data obtained from the monthly coal sampling and analysis shall be correllated with the results of the latest emission compliance test for the purpose of calculating mercury emission rate. Submit the results of the compliance testing to the DNR and the DNR will review the test results and adjust the emissions limit to more accurate reduction levels for mercury when the operation permit is issued.

Keep appropriate records to show that the boiler is equipped with low NOX burners.The permittee shall monitor the temperature of the flue gas entering the SCR and keep records of the flue gas temperature entering the SCR.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 41configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The data obtained from the monthly coal sampling and analysis shall be correllated with the results of the latest emission compliance test for the purpose of calculating mercury emission rate. Submit the results of the compliance testing to the DNR and the DNR will review the test results and adjust the emissions limit to more accurate reduction levels for mercury when the operation permit is issued.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 42configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall submit quarterly excess emission reports to the Department by January 30, April 30, July

30, and October 30 for the previous calendar quarter.Unless otherwise required by the Department in writing, this permit grants the permittee approval to submit a summary excess emission report in lieu of the full excess emission reports. This summary report shall be submitted on a Department form or in a format approved by the Department.

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 43configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 44configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 45configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 46configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 47configuration_pollutants1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall define normal performance in the Malfunction, Prevention and Abatement Plan that is approved in writing by the Department. The plan must include actions to be taken if parameters are measured outside the Plan range. The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected. The permittee shall retain copies of the results of the compliance emission tests.The permittee shall keep records of the ty pe and amount of fuel burned in each boiler on a monthly basis. The permittee shall record the parameters listed in A.1.b.(2) once every eight hours of operation or once per day , whichever yields the greater number of measurements.The permittee shall keep records of: (a) the date and name of the person or company performing the inspections required by A.1.b.(4); (b) a report that describes the unit and its design specifications, list of the items insp

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected.The permittee shall keep records of the ty pe and amount of fuel burned in this boiler on a monthly basis and the hours of operation of the ESP during the month..The permittee shall keep records of:(a) the date, time, and initials of the person performing the inspections required by I.A.1.b.(4) and (5);(b) a list of the items inspected; and(c) any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the amount of RPM and W ausau - Mosinee Mill ash received monthly and in a calendar year in tons.The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boilerThe permittee shall retain copies of the results of the compliance emission tests required.The permittee sha

The permittee shall prepare and follow a plan for periodic internal inspections of the boiler. This plan shall include the frequency of these inspections and the items to be inspected."The permittee shall keep records of: the date, time, and initials of the person performing the inspections required by I.C.1.b.(4) and (5) a list of the items inspected; and any maintenance or repairs performed as a result of these inspections. The permittee shall keep records of the ty pe and amount of fuel burned in the boiler on a monthly basis.The permittee shall keep records of the amount of RPM and W ausau Mosinee Mill ash received monthly and in a calendar year in tons. The permittee shall keep and maintain at the facility technical drawings, blueprints or equivalent records of the physical stack parameters for the boiler.The permittee shall record the parameters listed in I.C.1.b.(2) once every 8 hours of operation or once per day , whichever yields the greater number of measurements.The permittee sh

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 48configuration_pollutants1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1 The owner or operator of an emissions unit subject to the requirements of s. NR 446.05 shall determine and report to the Department, by March 1, annual mercury emissions for each emissions unit, beginning with calendar year 2010 emissions and ending with calendar year 2014 emissions, using the following formula: Annual Mercury Em issions = Fuel Use x Mercury Content of Fuel x Reduction of Mercury Prior to its Release to the Atmospherewhere:(a) Fuel use is the amount of fuel combusted in the combustion unit, as measured by the procedures specified in Appendices A, B, C and F of 40 CFR part 75, incorporated by reference in s. NR 484.04(26m)(a) to (d). The total amount of the fuel combusted in mmBtus may be apportioned to individual fuels, using consumption and delivery records for the fuels. (b) Mercury content of the fuel is determined according to ASTM D3684-01, incorporated by reference in s. NR 484.10(47m), or an equivalent method approved by the Department, following the procedures in s. NR 446.07(1

Page 49control_technologies

facility _id configuration_id

component_id

control_id project_title project_ty pe vendor_name

vndor_contact

vendor_phone 4072 8 P8 ACI 8 P8 ACI Non-Demonstration SPE-AMEREX Div of A-3 acquisition company

Dale Pfaff 6304067756118 4078 W3 W3 HG 3 W3ACI System Non-Demonstration

ADA Evironm ental Solutions

Jonathon S. Barr

3033398848 4078 W4 W4 HG 4 W4 ACI System Non-Demonstration

Babcock & W ilcox (sub. to ADA)

V. Matthan Kurian

3308602039

Page 50control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive 119 VIP Drive, Suite 204

We xford, PA 15090 4/1/2010 Activated carbon 8100 South Parkway , Unit B

Littleton CO 80120-4525 1/1/2010 Activated Carbon 20 S. VanBuren Ave. PO Box 351

Barberton OH 44203-0351 7/11/2008 Activated Carbon

Page 51control_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 Between boiler and ESP.

70 2.49 lb/TBtu 11.4 LB/MMACF

1.5 lb/TBtu 4 LB/MMACF

Page 52control_technologies

feed_rate_units LB/MMACF

LB/MMACF

Page 53control_coal_ranks

facility _id configuration_id

component_id

control_id coal_type 4072 8 P8 ACI 8 subbituminous 4078 W3 W3 HG 3 subbituminous 4078 W4 W4 HG 4 subbituminous

Page 54control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e 4072 8 P8 ACI 8 Total Mercury (Hgt) 4078 W3 W3 HG 3 Total Mercury (Hgt) 4078 W4 W4 HG 4 Total Mercury (Hgt)

Page 55control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year 4072 8 P8 ACI 8 Yes No 4078 W3 W3 HG 3 Yes No 4078 W4 W4 HG 4 No Yes

Page 56control_costs

CBI TRUE TRUE TRUE

Page 57mi sc_controls

facility _id mi sc_control_id

control_description 4072 1 No. 4078 1 No.

Page 58mi sc_control_configurations

facility _id mi sc_control_id

configuration_id 4072 1 5 4072 1 6 4072 1 7 4072 1 8 4078 1 W1 4078 1 W2 4078 1 W3 4078 1 W4

Page 59fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_type state_country other_country

county 4072 10-2009 10/1/2009 40703 short tons (2000 lbs) coal WY WY - Campbell 4072 11-2009 11/1/2009 13551 short tons (2000 lbs) coal WY WY - Campbell 4072 1-2009 1/1/2009 38791 short tons (2000 lbs) coal WY WY - Campbell 4072 12-2009 1/1/2009 52431 short tons (2000 lbs) coal WY WY - Converse 4072 13-2009 2/1/2009 26621 short tons (2000 lbs) coal WY WY - Converse 4072 14-2009 3/1/2009 12940 short tons (2000 lbs) coal WY WY - Converse 4072 15-2009 4/1/2009 13563 short tons (2000 lbs) coal WY WY - Converse 4072 16-2009 5/1/2009 13607 short tons (2000 lbs) coal WY WY - Converse 4072 17-2009 8/1/2009 27422 short tons (2000 lbs) coal WY WY - Converse 4072 18-2009 9/1/2009 53462 short tons (2000 lbs) coal WY WY - Converse 4072 19-2009 10/1/2009 67281 short tons (2000 lbs) coal WY WY - Converse 4072 20-2009 11/1/2009 67102 short tons (2000 lbs) coal WY WY - Converse 4072 21-2009 12/1/2009 81173 short tons (2000 lbs) coal WY WY - Converse 4072 2-2009 2/1/2009 52143 short tons (2000 lbs) coal WY WY - Campbell 4072 22-2009 1/1/2009 26238 short tons (2000 lbs) coal WY WY - Campbell 4072 23-2009 2/1/2009 52205 short tons (2000 lbs) coal WY WY - Campbell 4072 24-2009 3/1/2009 26238 short tons (2000 lbs) coal WY WY - Campbell 4072 25-2009 3/1/2009 13128 short tons (2000 lbs) coal WY WY - Campbell 4072 3-2009 3/1/2009 67037 short tons (2000 lbs) coal WY WY - Campbell 4072 4-2009 4/1/2009 40216 short tons (2000 lbs) coal WY WY - Campbell 4072 5-2009 5/1/2009 40530 short tons (2000 lbs) coal WY WY - Campbell 4072 6-2009 6/1/2009 27092 short tons (2000 lbs) coal WY WY - Campbell 4072 7-2009 7/1/2009 40356 short tons (2000 lbs) coal WY WY - Campbell 4072 8-2009 8/1/2009 27009 short tons (2000 lbs) coal WY WY - Campbell 4072 9-2009 9/1/2009 81574 short tons (2000 lbs) coal WY WY - Campbell 4078 04-2009 4/1/2009 55598 short tons (2000 lbs) coal WY WY - Campbell 4078 05-2009 5/1/2009 13923 short tons (2000 lbs) coal WY WY - Campbell 4078 07-2009 7/1/2009 72562 short tons (2000 lbs) coal WY WY - Campbell 4078 08-2009 8/1/2009 44175 short tons (2000 lbs) coal WY WY - Campbell 4078 09-2009 9/1/2009 75529 short tons (2000 lbs) coal WY WY - Campbell 4078 10-2009 10/1/2009 72602 short tons (2000 lbs) coal WY WY - Campbell 4078 11-2009 11/1/2009 90319 short tons (2000 lbs) coal WY WY - Campbell 4078 11-2009NA 11/1/2009 32423 short tons (2000 lbs) coal WY WY - Campbell 4078 1-2009 1/1/2009 62474 short tons (2000 lbs) coal WY WY - Campbell 4078 12-2009 12/1/2009 89912 short tons (2000 lbs) coal WY WY - Campbell 4078 12-2009NA 12/1/2009 63340 short tons (2000 lbs) coal WY WY - Campbell 4078 13-2009 1/1/2009 78580 short tons (2000 lbs) coal WY WY - Converse 4078 14-2009 2/1/2009 77883 short tons (2000 lbs) coal WY WY - Converse 4078 15-2009 3/1/2009 60767 short tons (2000 lbs) coal WY WY - Converse 4078 16-2009 4/1/2009 77459 short tons (2000 lbs) coal WY WY - Converse 4078 17-2009 5/1/2009 27668 short tons (2000 lbs) coal WY WY - Converse 4078 18-2009 6/1/2009 74974 short tons (2000 lbs) coal WY WY - Converse 4078 19-2009 7/1/2009 109615 short tons (2000 lbs) coal WY WY - Converse 4078 20-2009 8/1/2009 75760 short tons (2000 lbs) coal WY WY - Converse 4078 21-2009 9/1/2009 28176 short tons (2000 lbs) coal WY WY - Converse 4078 2-2009 2/1/2009 89426 short tons (2000 lbs) coal WY WY - Campbell 4078 2-2009A 2/1/2009 60724 short tons (2000 lbs) coal WY WY - Converse 4078 22-2009 10/1/2009 46346 short tons (2000 lbs) coal WY WY - Converse 4078 23-2009 11/1/2009 31282 short tons (2000 lbs) coal WY WY - Converse 4078 24-2009 12/1/2009 46373 short tons (2000 lbs) coal WY WY - Converse 4078 25-2009 6/1/2009 13544 short tons (2000 lbs) coal WY WY - Campbell

Page 60fuel_shipments

4078 26-2009 11/1/2009 13087 short tons (2000 lbs) coal WY WY - Campbell 4078 27-2009 10/1/2009 108655 short tons (2000 lbs) coal WY WY - Campbell 4078 28-2009 11/1/2009 154655 short tons (2000 lbs) coal WY WY - Campbell 4078 29-2009 12/1/2009 79802 short tons (2000 lbs) coal WY WY - Campbell 4078 30-2009 1/1/2009 1585 short tons (2000 lbs) coal WY WY - Campbell 4078 31-2009 2/1/2009 144992 short tons (2000 lbs) coal WY WY - Campbell 4078 3-2009 3/1/2009 74208 short tons (2000 lbs) coal WY WY - Campbell 4078 32-2009 2/1/2009 88725 short tons (2000 lbs) coal WY WY - Campbell 4078 33-2009 3/1/2009 121282 short tons (2000 lbs) coal WY WY - Campbell 4078 34-2009 4/1/2009 72721 short tons (2000 lbs) coal WY WY - Campbell 4078 35-2009 5/1/2009 75168 short tons (2000 lbs) coal WY WY - Campbell 4078 36-2009 6/1/2009 120144 short tons (2000 lbs) coal WY WY - Campbell 4078 37-2009 7/1/2009 134091 short tons (2000 lbs) coal WY WY - Campbell 4078 38-2008 8/1/2009 151310 short tons (2000 lbs) coal WY WY - Campbell 4078 39-2009 9/1/2009 170284 short tons (2000 lbs) coal WY WY - Campbell 4078 6-2009 6/1/2009 74585 short tons (2000 lbs) coal WY WY - Campbell

Page 61fuel_shipments

coal_seam shipment_method North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train North Antelope Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Black Thunder

Unit Train North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train North Antelope

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train North Antelope

Unit Train Black Thunder

Unit Train Black Thunder

Unit Train North Antelope

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Black Thunder

Unit Train Antelope Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train Antelope (Converse)

Unit Train North Antelope

Unit Train

Page 62fuel_shipments

North Antelope

Unit Train East Thunder

Unit Train East Thunder

Unit Train East Thunder

Unit Train Black Thunder

Unit Train Jacobs Ranch

Unit Train Black Thunder

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Jacobs Ranch

Unit Train Black Thunder

Unit Train

Page 63fuel_shipment_configurations

facility _id shipment_id

configuration_id 4072 10-2009 5 4072 10-2009 6 4072 10-2009 7 4072 10-2009 8 4072 11-2009 5 4072 11-2009 6 4072 11-2009 7 4072 11-2009 8 4072 1-2009 5 4072 1-2009 6 4072 1-2009 7 4072 1-2009 8 4072 12-2009 5 4072 12-2009 6 4072 12-2009 7 4072 12-2009 8 4072 13-2009 5 4072 13-2009 6 4072 13-2009 7 4072 13-2009 8 4072 14-2009 5 4072 14-2009 6 4072 14-2009 7 4072 14-2009 8 4072 15-2009 5 4072 15-2009 6 4072 15-2009 7 4072 15-2009 8 4072 16-2009 5 4072 16-2009 6 4072 16-2009 7 4072 16-2009 8 4072 17-2009 5 4072 17-2009 6 4072 17-2009 7 4072 17-2009 8 4072 18-2009 5 4072 18-2009 6 4072 18-2009 7 4072 18-2009 8 4072 19-2009 5 4072 19-2009 6 4072 19-2009 7 4072 19-2009 8 4072 20-2009 5 4072 20-2009 6 4072 20-2009 7 4072 20-2009 8 4072 21-2009 5 4072 21-2009 6 4072 21-2009 7

Page 64fuel_shipment_configurations

4072 21-2009 8 4072 2-2009 5 4072 2-2009 6 4072 2-2009 7 4072 2-2009 8 4072 22-2009 5 4072 22-2009 6 4072 22-2009 7 4072 22-2009 8 4072 23-2009 5 4072 23-2009 6 4072 23-2009 7 4072 23-2009 8 4072 24-2009 5 4072 24-2009 6 4072 24-2009 7 4072 24-2009 8 4072 25-2009 5 4072 25-2009 6 4072 25-2009 7 4072 25-2009 8 4072 3-2009 5 4072 3-2009 6 4072 3-2009 7 4072 3-2009 8 4072 4-2009 5 4072 4-2009 6 4072 4-2009 7 4072 4-2009 8 4072 5-2009 5 4072 5-2009 6 4072 5-2009 7 4072 5-2009 8 4072 6-2009 5 4072 6-2009 6 4072 6-2009 7 4072 6-2009 8 4072 7-2009 5 4072 7-2009 6 4072 7-2009 7 4072 7-2009 8 4072 8-2009 5 4072 8-2009 6 4072 8-2009 7 4072 8-2009 8 4072 9-2009 5 4072 9-2009 6 4072 9-2009 7 4072 9-2009 8 4078 04-2009 W1 4078 04-2009 W2 4078 04-2009 W3

Page 65fuel_shipment_configurations

4078 05-2009 W1 4078 05-2009 W2 4078 05-2009 W3 4078 07-2009 W1 4078 07-2009 W2 4078 07-2009 W3 4078 08-2009 W1 4078 08-2009 W2 4078 08-2009 W3 4078 09-2009 W1 4078 09-2009 W2 4078 09-2009 W3 4078 10-2009 W1 4078 10-2009 W2 4078 10-2009 W3 4078 11-2009 W1 4078 11-2009 W2 4078 11-2009 W3 4078 11-2009NAW4 4078 1-2009 W1 4078 1-2009 W2 4078 1-2009 W3 4078 12-2009 W1 4078 12-2009 W2 4078 12-2009 W3 4078 12-2009NAW4 4078 13-2009 W1 4078 13-2009 W2 4078 13-2009 W3 4078 14-2009 W1 4078 14-2009 W2 4078 14-2009 W3 4078 15-2009 W1 4078 15-2009 W2 4078 15-2009 W3 4078 16-2009 W1 4078 16-2009 W2 4078 16-2009 W3 4078 17-2009 W1 4078 17-2009 W2 4078 17-2009 W3 4078 18-2009 W1 4078 18-2009 W2 4078 18-2009 W3 4078 19-2009 W1 4078 19-2009 W2 4078 19-2009 W3 4078 20-2009 W1 4078 20-2009 W2 4078 20-2009 W3 4078 21-2009 W1 4078 21-2009 W2

Page 66fuel_shipment_configurations

4078 21-2009 W3 4078 2-2009 W1 4078 2-2009 W2 4078 2-2009 W3 4078 2-2009A W4 4078 22-2009 W1 4078 22-2009 W2 4078 22-2009 W3 4078 23-2009 W1 4078 23-2009 W2 4078 23-2009 W3 4078 24-2009 W1 4078 24-2009 W2 4078 24-2009 W3 4078 25-2009 W1 4078 25-2009 W2 4078 25-2009 W3 4078 26-2009 W1 4078 26-2009 W2 4078 26-2009 W3 4078 27-2009 W4 4078 28-2009 W4 4078 29-2009 W4 4078 30-2009 W4 4078 31-2009 W4 4078 3-2009 W1 4078 3-2009 W2 4078 3-2009 W3 4078 32-2009 W4 4078 33-2009 W4 4078 34-2009 W4 4078 35-2009 W4 4078 36-2009 W4 4078 37-2009 W4 4078 38-2008 W4 4078 39-2009 W4 4078 6-2009 W1 4078 6-2009 W2 4078 6-2009 W3

Page 67fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units

Page 68fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_ty pe

supplier_name

supplier_address

Page 69fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies

Page 70fuel_shipment_samples

analysis_copies

Page 71fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL

Page 72test_reports

facility _id report_id report_type other_type report_description report_begin_date

report_end_date

before_control

during_deviation 4072 P3 Hg 2006

compliance Determination of baseline Hg emissions 3/22/2006 3/22/2006 No No 4072 P4 Hg 2006

compliance Determination of baseline Hg emissions 3/22/2006 3/22/2006 No No 4072 P5 Hg 2006

compliance Determination of baseline Hg emissions. 3/22/2006 3/22/2006 No No 4072 P5 PM 2008

compliance Particulate Matter Compliance Test (2008) 8/12/2008 8/12/2008 No No 4072 P6 Hg 2006

compliance Determination of baseline Hg emissions. 3/22/2006 3/22/2006 No No 4072 P7 Hg 2006

compliance Determination of baseline Hg emissions. 3/22/2006 3/22/2006 No No 4072 P7 PM 2008

compliance Particulate Matter Compliance Test (2008) 8/13/2008 8/13/2008 No No 4072 P8 Hg 2006

compliance Determination of baseline Hg emissions. 3/21/2006 3/21/2006 No No 4072 P8 PM 2008

compliance Particulate Matter Compliance Test (2008) 8/14/2008 8/14/2008 No No 4078 W1 Hg 2006

compliance Hg emissions baseline determination 3/16/2006 3/16/2006 No No 4078 W1 PM 2005

compliance PM Compliance Test ######## ######## No No 4078 W1 PM 2009

compliance PM compliance test 2009 8/25/2009 8/25/2009 No No 4078 W2 Hg 2006

compliance Hg emissions baseline determination. 3/16/2006 3/16/2006 No No 4078 W2 PM 2005

compliance PM Compliance Test 2005 ######## ######## No No 4078 W2 PM 2009

compliance PM compliance test 2009 8/27/2009 8/27/2009 No No 4078 W3Hg 2006

compliance Hg emissions baseline. 3/15/2006 3/15/2006 No No 4078 W3PM 2005

compliance PM compliance test 2005 ######## ######## No No 4078 W3PM 2009

compliance PM compliance test 2009 8/14/2009 8/14/2009 No No 4078 W4 CO 2008

compliance W4 CO Method 10 2008 7/9/2008 7/9/2008 No No 4078 W4 HCl 2008

compliance We ston 4 HCl compliance test 2008 7/10/2008 7/10/2008 No No 4078 W4 Hg 1-2009

compliance W4 Hg compliance test 1/27/2009 1/27/2009 1/27/2009 No No 4078 W4 Hg 7-2008

compliance We ston 4 Hg compliance test 7/9/2008 7/9/2008 7/9/2008 No No 4078 W4 Hg 7-2009

compliance W4 Hg compliance test 7/10/2009 7/10/2009 7/10/2009 No No 4078 W4 M13B Fluoride

compliance W4 M13B Fluoride 2008 7/9/2008 7/9/2008 No No 4078 W4 Metals 2008

compliance Method 29 Metals Determination 2008. 7/11/2008 7/11/2008 No No 4078 W4 PM M201A 2008

compliance Method 201A PM compliance test. 7/10/2008 7/10/2008 No No 4078 W4 PM M5B 2008

compliance Method 5B PM compliance test. 7/9/2008 7/11/2008 No No

Page 73test_reports

deviation_reports 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 No No

Page 74test_report_configurations

facility _id report_id configuration_id 4072 P3 Hg 2006

3 4072 P4 Hg 2006

4 4072 P5 Hg 2006

5 4072 P5 PM 2008

5 4072 P5 PM 2008

6 4072 P6 Hg 2006

6 4072 P7 Hg 2006

7 4072 P7 PM 2008

7 4072 P8 Hg 2006

8 4072 P8 PM 2008

8 4078 W1 Hg 2006

W1 4078 W1 PM 2005

W1 4078 W1 PM 2009

W1 4078 W2 Hg 2006

W2 4078 W2 PM 2005

W2 4078 W2 PM 2009

W2 4078 W3Hg 2006

W3 4078 W3PM 2005

W3 4078 W3PM 2009

W3 4078 W4 CO 2008

W4 4078 W4 HCl 2008

W4 4078 W4 Hg 1-2009

W4 4078 W4 Hg 7-2008

W4 4078 W4 Hg 7-2009

W4 4078 W4 M13B Fluoride

W4 4078 W4 Metals 2008

W4 4078 W4 PM M201A 2008

W4 4078 W4 PM M5B 2008

W4

Page 75test_report_fuels

facility _id report_id fuel_id 4072 P3 Hg 2006

coal 4072 P4 Hg 2006

coal 4072 P5 Hg 2006

coal 4072 P5 PM 2008

coal 4072 P6 Hg 2006

coal 4072 P7 Hg 2006

coal 4072 P7 PM 2008

coal 4072 P8 Hg 2006

coal 4072 P8 PM 2008

coal 4078 W1 Hg 2006

coal 4078 W1 PM 2005

coal 4078 W1 PM 2009

coal 4078 W2 Hg 2006

coal 4078 W2 PM 2005

coal 4078 W2 PM 2009

coal 4078 W3Hg 2006

coal 4078 W3PM 2005

coal 4078 W3PM 2009

Coal 4078 W4 CO 2008

Coal 4078 W4 HCl 2008

Coal 4078 W4 Hg 1-2009

Coal 4078 W4 Hg 7-2008

Coal 4078 W4 Hg 7-2009

Coal 4078 W4 M13B Fluoride

Coal 4078 W4 Metals 2008

Coal 4078 W4 PM M201A 2008

coal 4078 W4 PM M5B 2008

Coal

Page 76test_report_fuel_ty pes

facility _id report_id fuel_id fuel_type percentage_massvol percentage_btu

other_type 4072 P3 Hg 2006

coal coal - subbituminous 100 100 4072 P4 Hg 2006

coal coal - subbituminous 100 100 4072 P5 Hg 2006

coal coal - subbituminous 100 100 4072 P5 PM 2008

coal coal - subbituminous 100 100 4072 P6 Hg 2006

coal coal - subbituminous 100 100 4072 P7 Hg 2006

coal coal - subbituminous 100 100 4072 P7 PM 2008

coal coal - subbituminous 100 100 4072 P8 Hg 2006

coal coal - subbituminous 100 100 4072 P8 PM 2008

coal coal - subbituminous 100 100 4078 W1 Hg 2006

coal coal - subbituminous 100 100 4078 W1 PM 2005

coal coal - subbituminous 100 100 4078 W1 PM 2009

coal coal - subbituminous 100 100 4078 W2 Hg 2006

coal coal - subbituminous 100 100 4078 W2 PM 2005

coal coal - subbituminous 100 100 4078 W2 PM 2009

coal coal - subbituminous 100 100 4078 W3Hg 2006

coal coal - subbituminous 100 100 4078 W3PM 2005

coal coal - subbituminous 100 100 4078 W3PM 2009

Coal coal - subbituminous 100 100 4078 W4 CO 2008

Coal coal - subbituminous 100 100 4078 W4 HCl 2008

Coal coal - subbituminous 100 100 4078 W4 Hg 1-2009

Coal coal - subbituminous 100 100 4078 W4 Hg 7-2008

Coal coal - subbituminous 100 100 4078 W4 Hg 7-2009

Coal coal - subbituminous 100 100 4078 W4 M13B Fluoride

Coal coal - subbituminous 100 100 4078 W4 Metals 2008

Coal coal - subbituminous 100 100 4078 W4 PM M201A 2008

coal coal - subbituminous 100 100 4078 W4 PM M5B 2008

Coal coal - subbituminous 100 100

Page 77cem_data

facility _id tim e_period

cem_period_description 4072 1/1/2005 to 12/31/2009

Pulliam units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (unit 8 only) and CO process monitors are also installed at Pulliam. The Hg monitor is not currently in operation. 4078 1/1/2005 to 12/31/2009

We ston units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (units 3 and 4 only) and CO process monitors are also installed at W eston. Hg monitor on unit 3 not in operation.

Page 78cem_data

Pulliam units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (unit 8 only) and CO process monitors are also installed at Pulliam. The Hg monitor is not currently in operation. We ston units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (units 3 and 4 only) and CO process monitors are also installed at W eston. Hg monitor on unit 3 not in operation.

Page 79cem_data

Pulliam units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (unit 8 only) and CO process monitors are also installed at Pulliam. The Hg monitor is not currently in operation. We ston units have installed certified COMs (opacity monitors) with historical data available up to five years. Non-certified Hg (units 3 and 4 only) and CO process monitors are also installed at W eston. Hg monitor on unit 3 not in operation.

Page 80cem_data_pollutants1

facility _id tim e_period

pollutant_nam e

Page 81test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_by pass_percent

testing_bypass_percent 4072 P3 Hg 2006

CS34 Port No No 4072 P4 Hg 2006

CS34 Port No No 4072 P5 Hg 2006

CS56 Port No No 4072 P5 PM 2008

CS56 Port No No 4072 P6 Hg 2006

CS56 Port No No 4072 P7 Hg 2006

P7 Port No No 4072 P7 PM 2008

P7 Port No No 4072 P8 Hg 2006

P8 Port No No 4072 P8 PM 2008

P8 Port No No 4078 W1 Hg 2006

W1 Port No No 4078 W1 PM 2005

W1 Port No No 4078 W1 PM 2009

W1 Port No No 4078 W2 Hg 2006

W2 Port No No 4078 W2 PM 2005

W2 Port No No 4078 W2 PM 2009

W2 Port No No 4078 W3Hg 2006

W3Port No No 4078 W3PM 2005

W3Port No No 4078 W3PM 2009

W3Port No No 4078 W4 CO 2008

W4 Port No No 4078 W4 HCl 2008

W4 Port No No 4078 W4 Hg 1-2009

W4 Port No No 4078 W4 Hg 7-2008

W4 Port No No 4078 W4 Hg 7-2009

W4 Port No No 4078 W4 M13B Fluoride

W4 Port No No 4078 W4 Metals 2008

W4 Port No No 4078 W4 PM M201A 2008

W4 Port No No 4078 W4 PM M5B 2008

W4 Port No No

Page 82test_report_sampling

fg_fraction 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100 100% 100% 100% 100%

Page 83sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 4072 P3 Hg 2006

CS34 Port 1 3/22/2006 3/22/2006 21 20 4072 P3 Hg 2006

CS34 Port 2 3/22/2006 3/22/2006 21 20 4072 P3 Hg 2006

CS34 Port 3 3/22/2006 3/22/2006 21 20 4072 P4 Hg 2006

CS34 Port 1 3/22/2006 3/22/2006 24 22 4072 P4 Hg 2006

CS34 Port 2 3/22/2006 3/22/2006 24 22 4072 P4 Hg 2006

CS34 Port 3 3/22/2006 3/22/2006 24 22 4072 P5 Hg 2006

CS56 Port 1 3/21/2006 3/21/2006 52 49 4072 P5 Hg 2006

CS56 Port 2 3/21/2006 3/21/2006 52 49 4072 P5 Hg 2006

CS56 Port 3 3/21/2006 3/21/2006 52 49 4072 P5 PM 2008

CS56 Port 1 8/12/2008 8/12/2008 108 102 8.4 4072 P5 PM 2008

CS56 Port 2 8/12/2008 8/12/2008 108 102 10.4 4072 P5 PM 2008

CS56 Port 3 8/12/2008 8/12/2008 108 102 10.4 4072 P6 Hg 2006

CS56 Port 1 3/21/2006 3/21/2006 70 66 4072 P6 Hg 2006

CS56 Port 2 3/21/2006 3/21/2006 70 66 4072 P6 Hg 2006

CS56 Port 3 3/21/2006 3/21/2006 70 66 4072 P7 Hg 2006

P7 Port 1 3/22/2006 3/22/2006 80 75 4072 P7 Hg 2006

P7 Port 2 3/22/2006 3/22/2006 80 75 4072 P7 Hg 2006

P7 Port 3 3/22/2006 3/22/2006 80 75 4072 P7 PM 2008

P7 Port 1 8/13/2008 8/13/2008 74 67 9.5 4072 P7 PM 2008

P7 Port 2 8/13/2008 8/13/2008 74 67 10.8 4072 P7 PM 2008

P7 Port 3 8/13/2008 8/13/2008 74 67 10.8 4072 P8 Hg 2006

P8 Port 1 3/21/2006 3/21/2006 127 120 4072 P8 Hg 2006

P8 Port 2 3/21/2006 3/21/2006 127 120 4072 P8 Hg 2006

P8 Port 3 3/21/2006 3/21/2006 127 120 4072 P8 PM 2008

P8 Port 1 8/14/2008 8/14/2008 127 119 11.1 4072 P8 PM 2008

P8 Port 2 8/14/2008 8/14/2008 127 119 10.7 4072 P8 PM 2008

P8 Port 3 8/14/2008 8/14/2008 127 119 10.9 4078 W1 Hg 2006

W1 Port 1 3/16/2006 3/16/2006 55 51 4078 W1 Hg 2006

W1 Port 2 3/16/2006 3/16/2006 55 51 4078 W1 Hg 2006

W1 Port 3 3/16/2006 3/16/2006 55 51 4078 W1 PM 2005

W1 Port 1 ######## ######## 54 50 8.1 4078 W1 PM 2005

W1 Port 2 ######## ######## 54 50 9.3 4078 W1 PM 2005

W1 Port 3 ######## ######## 54 50 9.8 4078 W1 PM 2009

W1 Port 1 8/25/2009 8/25/2009 59 55 11.3 4078 W1 PM 2009

W1 Port 2 8/25/2009 8/25/2009 59 55 11.7 4078 W1 PM 2009

W1 Port 3 8/25/2009 8/25/2009 59 55 11.6 4078 W2 Hg 2006

W2 Port 1 3/16/2006 3/16/2006 81 76 4078 W2 Hg 2006

W2 Port 2 3/16/2006 3/16/2006 81 76 4078 W2 Hg 2006

W2 Port 3 3/16/2006 3/16/2006 81 76 4078 W2 PM 2005

W2 Port 1 ######## ######## 89 76 6.5 4078 W2 PM 2005

W2 Port 2 ######## ######## 89 76 7.2 4078 W2 PM 2005

W2 Port 3 ######## ######## 89 76 7.7 4078 W2 PM 2009

W2 Port 1 8/27/2009 8/27/2009 81 76 11.3 4078 W2 PM 2009

W2 Port 2 8/27/2009 8/27/2009 81 76 11.4 4078 W2 PM 2009

W2 Port 3 8/27/2009 8/27/2009 81 76 12 4078 W3Hg 2006

W3Port 1 3/15/2006 3/15/2006 341 312 4078 W3Hg 2006

W3Port 2 3/15/2006 3/15/2006 341 312 4078 W3Hg 2006

W3Port 3 3/15/2006 3/15/2006 341 312 4078 W3PM 2005

W3Port 1 ######## ######## 341 312 11.6 4078 W3PM 2005

W3Port 2 ######## ######## 341 312 9.1 4078 W3PM 2005

W3Port 3 ######## ######## 341 312 12.7

Page 84sampling_runs

4078 W3PM 2009

W3Port 1 8/14/2009 8/14/2009 341 312 11.5 4078 W3PM 2009

W3Port 2 8/14/2009 8/14/2009 341 312 10.5 4078 W3PM 2009

W3Port 3 8/14/2009 8/14/2009 341 312 10.4 4078 W4 CO 2008

W4 Port 1 7/9/2008 7/9/2008 4078 W4 CO 2008

W4 Port 2 7/9/2008 7/9/2008 4078 W4 CO 2008

W4 Port 3 7/9/2008 7/9/2008 4078 W4 HCl 2008

W4 Port 1 7/10/2008 7/10/2008 15.9 4078 W4 HCl 2008

W4 Port 2 7/10/2008 7/10/2008 14.2 4078 W4 HCl 2008

W4 Port 3 7/10/2008 7/10/2008 15.6 4078 W4 Hg 1-2009

W4 Port 1 1/27/2009 1/27/2009 520 480 4078 W4 Hg 1-2009

W4 Port 2 1/27/2009 1/27/2009 520 480 4078 W4 Hg 1-2009

W4 Port 3 1/27/2009 1/27/2009 520 480 4078 W4 Hg 7-2008

W4 Port 1 7/9/2008 7/9/2008 520 480 4078 W4 Hg 7-2008

W4 Port 2 7/9/2008 7/9/2008 520 480 4078 W4 Hg 7-2008

W4 Port 3 7/9/2008 7/9/2008 520 480 4078 W4 Hg 7-2009

W4 Port 1 7/10/2009 7/10/2009 580 530 4078 W4 Hg 7-2009

W4 Port 2 7/10/2009 7/10/2009 580 530 4078 W4 Hg 7-2009

W4 Port 3 7/10/2009 7/10/2009 580 530 4078 W4 M13B Fluoride

W4 Port 1 7/9/2008 7/9/2008 16.3 4078 W4 M13B Fluoride

W4 Port 2 7/9/2008 7/9/2008 16.4 4078 W4 M13B Fluoride

W4 Port 3 7/9/2008 7/9/2008 16.4 4078 W4 Metals 2008

W4 Port 1 7/11/2008 7/11/2008 15.6 4078 W4 Metals 2008

W4 Port 2 7/11/2008 7/11/2008 15.8 4078 W4 Metals 2008

W4 Port 3 7/11/2008 7/11/2008 15.2 4078 W4 PM M201A 2008

W4 Port 1 7/10/2008 7/10/2008 15.5 4078 W4 PM M201A 2008

W4 Port 2 7/10/2008 7/10/2008 15.9 4078 W4 PM M201A 2008

W4 Port 3 7/10/2008 7/10/2008 15.2 4078 W4 PM M5B 2008

W4 Port 1 7/9/2008 7/9/2008 14.4 4078 W4 PM M5B 2008

W4 Port 2 7/9/2008 7/9/2008 15.1 4078 W4 PM M5B 2008

W4 Port 3 7/9/2008 7/9/2008 14.7

Page 85sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 145700 dscfm 68 1 7.9 12.3 300 136800 dscfm 68 1 7.2 12.9 142400 dscfm 68 1 7.4 12.8 300 145700 dscfm 68 1 7.9 12.3 300 136800 dscfm 68 1 7.2 12.9 300 142400 dscfm 7.4 12.8 300 337600 dscfm 68 1 6.4 13.8 300 331700 dscfm 68 1 6.4 13.8 300 331900 dscfm 68 1 6.6 13.6 300 307388 dscfm 68 1 6.5 12.5 300 299100 dscfm 68 1 6.5 12.8 300 297263 dscfm 68 1 6.5 13 300 337600 dscfm 68 1 6.4 13.8 300 331700 dscfm 68 1 6.4 13.8 300 331900 dscfm 68 1 6.6 13.6 300 179800 dscfm 68 1 5.3 14.8 300 185100 dscfm 68 1 5.7 14.3 300 200400 dscfm 68 1 6.9 13.3 300 189116 dscfm 68 1 7 12.2 300 190167 dscfm 68 1 7 12 300 187268 dscfm 68 1 7 12 300 310500 dscfm 68 1 5.7 14.4 300 310300 dscfm 68 1 5.7 14.4 300 301800 dscfm 1 68 5.6 14.5 300 313071 dscfm 68 1 7 12 300 304126 dscfm 68 1 7 12 300 302978 dscfm 68 1 6.8 12.3 300 154800 dscfm 68 1 6.2 13.9 300 159300 dscfm 68 1 6.3 13.9 300 157300 dscfm 68 1 6.1 14 300 159345 dscfm 68 1 5.5 13.5 300 151213 dscfm 68 1 5 13.5 300 147747 dscfm 68 1 5.5 13.5 300 171493 dscfm 68 1 9 11.5 300 167172 dscfm 68 1 9 11.5 300 166652 dscfm 68 1 9 11.5 300 184000 dscfm 68 1 7.9 12.4 300 184200 dscfm 68 1 9.3 11 300 176900 dscfm 68 1 5.3 14.8 300 208025 dscfm 68 1 4.8 13.4 300 203580 dscfm 68 1 5 13.6 300 197841 dscfm 68 1 5 13.6 300 180811 dscfm 68 1 6.5 14 300 185617 dscfm 68 1 6.5 14 300 185733 dscfm 68 1 6.5 14 300 766200 dscfm 68 1 4.5 15.6 300 768000 dscfm 68 1 4.4 15.7 300 793200 dscfm 68 1 5 15 300 717886 dscfm 68 1 4.4 14.7 300 756400 dscfm 68 1 4.4 14.8 300 729086 dscfm 68 1 4.4 14.8 300

Page 86sampling_runs

755758 dscfm 68 1 5.5 15 300 774404 dscfm 68 1 5.5 15 300 792471 dscfm 68 1 5.5 15 300 68 1 4.7 14.4 68 1 4.7 14.5 68 1 4.6 14.5 1032330 dscfm 68 1 4.7 14.6 180.8 1091638 dscfm 68 1 4.7 14.6 179.7 1065215 dscfm 68 1 4.7 14.6 180.4 68 1 5.2 68 1 5.3 68 1 5.2 68 1 4.65 68 1 4.65 68 1 4.65 68 1 6.1 13.1 68 1 6.1 13.1 68 1 6.4 12.9 1069386 dscfm 68 1 4.7 14.6 179.7 1054553 dscfm 68 1 4.7 14.6 180.6 1057726 dscfm 68 1 4.4 14.6 181.1 1043149 dscfm 68 1 4.7 16.6 176.3 1064713 dscfm 68 1 4.7 14.6 178.1 1077615 dscfm 68 1 4.7 14.6 178.6 1149738 dscfm 68 1 4.65 14.6 179.1 1184093 dscfm 68 1 4.65 14.6 178.9 1189164 dscfm 68 1 4.65 14.6 178.1 1001549 dscfm 68 1 4.7 14.6 179.9 1029639 dscfm 68 1 4.7 14.6 179.8 1021596 dscfm 68 1 4.7 14.6 178.8

Page 87sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value 0.9866 0.39 29 coal 21 7.07 12033 0.9859 1 29 coal 21 6.88 11939 0.9859 0.8 29 coal 21 7.41 11940 0.9866 1.32 29 coal 24 7.07 12033 0.9859 0.81 29 coal 24 6.88 11939 0.9859 0.73 29 coal 24 7.41 11940 0.9873 0.84 29 coal 52 6.65 11964 0.9869 0.74 29 coal 52 6.65 11996 0.9859 0.95 29 coal 52 6.84 12032 0.9722 Method 5/202 0.9722 Method 5/202 0.9722 Method 5/202 0.9873 0.71 29 coal 70 6.65 11964 0.9869 0.52 29 coal 70 6.65 11996 0.9859 0.44 29 coal 70 6.84 12032 0.9866 0.24 29 coal 80 6.46 12039 0.9859 0.31 29 coal 80 6.61 11994 0.9859 0.28 29 coal 80 6.4 12017 0.9679 Method 5/202 0.9679 Method 5/202 0.9679 Method 5/202 0.9873 0.46 29 coal 127 6.63 11978 0.9876 0.43 29 coal 127 6.77 11950 0.9869 0.53 29 coal 127 6.62 11979 0.9712 Method 5/202 0.9712 Method 5/202 0.9712 Method 5/202 0.9659 0.38 Method 29 coal 55 57018 8.24 11871 0.9659 0.45 Method 29 coal 55 58178 8.08 11857 0.9659 0.44 Method 29 coal 55 57725 7.35 11974 0.9552 Method 5/202 0.9552 Method 5/202 0.9552 Method 5/202 0.9582 Method 5/OTM 28 0.9582 Method 5/OTM 28 0.9582 Method 5/OTM 28 0.9659 0.49 Method 29 coal 81 59450 7.81 11848 0.9659 0.43 Method 29 coal 81 53788 8.38 11791 0.9659 0.33 Method 29 coal 81 69654 8.41 11762 0.9582 Method 5/202 0.9582 Method 5/202 0.9582 Method 5/202 0.9538 Method 5/OTM 28 0.9538 Method 5/OTM 28 0.9538 Method 5/OTM 28 0.9665 0.83 Method 29 coal 341 6.31 11988 0.9665 0.27 Method 29 coal 341 6.44 11978 0.9665 0.78 Method 29 coal 341 6.75 11913 0.9555 Method 5/202 0.9555 Method 5/202 0.9555 Method 5/202

Page 88sampling_runs

0.9522 Method 5/OTM 28 0.9522 Method 5/OTM 28 0.9522 Method 5/OTM 28

10, 6C, 7E 10, 6C, 7E 10, 6C, 7E 0.9468 26A 0.9468 26 0.9468 26A 0.9679 30B 0.9679 30B 0.9679 30B

30B 30B 30B 0.9485 30B 0.9485 30B 0.9486 30B 0.9458 13B 0.9458 13B 0.9458 13B 0.9458 29 0.9462 29 0.9458 29 0.9472 201A/OTM 28 0.9472 201A/OTM 28 0.9472 201A/OTM 28 0.9458 5B/OTM 28 0.9458 5B/OTM 28 0.9458 5B/OTM 28

Page 89sampling_runs

fuel_sulfur 0.53 0.51 0.54 0.53 0.51 0.54 0.48 0.5 0.49

0.48 0.5 0.49 0.47 0.51 0.42

0.5 0.47 0.49

0.4 0.4 0.39

0.4 0.38 0.4

0.36 0.35 0.38

Page 90sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 4072 P5 Hg 2006

CS56 Port 3 Total Mercury (Hgt) 10.19 mi crogram per dry standard cubic meter ( FALSE 4072 P6 Hg 2006

CS56 Port 1 Total Mercury (Hgt) 10.04 mi crogram per dry standard cubic meter ( FALSE 4072 P6 Hg 2006

CS56 Port 2 Total Mercury (Hgt) 9.24 mi crogram per dry standard cubic meter ( FALSE 4072 P7 Hg 2006

P7 Port 1 Total Mercury (Hgt) 10.71 mi crogram per dry standard cubic meter ( FALSE 4072 P7 Hg 2006

P7 Port 2 Total Mercury (Hgt) 10.09 mi crogram per dry standard cubic meter ( FALSE 4072 P7 Hg 2006

P7 Port 3 Total Mercury (Hgt) 9.54 mi crogram per dry standard cubic meter ( FALSE 4072 P8 Hg 2006

P8 Port 1 Total Mercury (Hgt) 8.84 mi crogram per dry standard cubic meter ( FALSE 4072 P5 PM 2008

CS56 Port 1 PM (Filterable) 0.0113 FALSE 4072 P5 PM 2008

CS56 Port 1 PM (Condensable) 0.0141 FALSE 4072 P5 PM 2008

CS56 Port 2 PM (Filterable) 0.0091 FALSE 4072 P5 PM 2008

CS56 Port 2 PM (Condensable) 0.0156 FALSE 4072 P5 PM 2008

CS56 Port 3 PM (Filterable) 0.0103 FALSE 4072 P5 PM 2008

CS56 Port 3 PM (Condensable) 0.0195 FALSE 4072 P7 PM 2008

P7 Port 1 PM (Filterable) 0.0098 FALSE 4072 P7 PM 2008

P7 Port 1 PM (Condensable) 0.0118 FALSE 4072 P7 PM 2008

P7 Port 2 PM (Filterable) 0.0089 FALSE 4072 P7 PM 2008

P7 Port 2 PM (Condensable) 0.0112 FALSE 4072 P7 PM 2008

P7 Port 3 PM (Filterable) 0.0084 FALSE 4072 P7 PM 2008

P7 Port 3 PM (Condensable) 0.0113 FALSE 4072 P8 PM 2008

P8 Port 1 PM (Filterable) 0.0066 FALSE 4072 P8 PM 2008

P8 Port 1 PM (Condensable) 0.0107 FALSE 4072 P8 PM 2008

P8 Port 2 PM (Filterable) 0.0072 FALSE 4072 P8 PM 2008

P8 Port 2 PM (Condensable) 0.0114 FALSE 4072 P8 PM 2008

P8 Port 3 PM (Filterable) 0.0065 FALSE 4072 P8 PM 2008

P8 Port 3 PM (Condensable) 0.0089 FALSE 4078 W1 PM 2005

W1 Port 1 PM (Filterable) 0.0338 FALSE 4078 W1 PM 2005

W1 Port 1 PM (Condensable) 0.0058 FALSE 4078 W1 PM 2005

W1 Port 2 PM (Filterable) 0.0322 FALSE 4078 W1 PM 2005

W1 Port 2 PM (Condensable) 0.0073 FALSE 4078 W1 PM 2005

W1 Port 3 PM (Filterable) 0.0305 FALSE 4078 W1 PM 2005

W1 Port 3 PM (Condensable) 0.0087 FALSE 4078 W2 PM 2005

W2 Port 1 PM (Filterable) 0.026 FALSE 4078 W2 PM 2005

W2 Port 1 PM (Condensable) 0.0029 FALSE 4078 W2 PM 2005

W2 Port 2 PM (Filterable) 0.039 FALSE 4078 W2 PM 2005

W2 Port 2 PM (Condensable) 0.0023 FALSE 4078 W2 PM 2005

W2 Port 3 PM (Filterable) 0.0369 FALSE 4078 W2 PM 2005

W2 Port 3 PM (Condensable) 0.0022 FALSE 4078 W3PM 2005

W3Port 1 PM (Filterable) 0.004 FALSE 4078 W3PM 2005

W3Port 1 PM (Condensable) 0.009 FALSE 4078 W3PM 2005

W3Port 2 PM (Filterable) 0.0062 FALSE 4078 W3PM 2005

W3Port 2 PM (Condensable) 0.018 FALSE 4078 W3PM 2005

W3Port 3 PM (Filterable) 0.006 FALSE 4078 W3PM 2005

W3Port 3 PM (Condensable) 0.0093 FALSE 4078 W1 PM 2009

W1 Port 1 PM (Filterable) 0.0162 FALSE 4078 W1 PM 2009

W1 Port 1 PM (Condensable) 0.0026 FALSE 4078 W1 PM 2009

W1 Port 2 PM (Filterable) 0.0159 FALSE 4078 W1 PM 2009

W1 Port 2 PM (Condensable) 0.0121 FALSE 4078 W1 PM 2009

W1 Port 3 PM (Filterable) 0.0142 FALSE 4078 W1 PM 2009

W1 Port 3 PM (Condensable) 0.008 FALSE 4078 W2 PM 2009

W2 Port 1 PM (Filterable) 0.0168 FALSE 4078 W2 PM 2009

W2 Port 1 PM (Condensable) 0.0018 FALSE

Page 91sampling_run_pollutants1

4078 W2 PM 2009

W2 Port 2 PM (Filterable) 0.0161 FALSE 4078 W2 PM 2009

W2 Port 2 PM (Condensable) 0.0037 FALSE 4078 W2 PM 2009

W2 Port 3 PM (Filterable) 0.0153 FALSE 4078 W2 PM 2009

W2 Port 3 PM (Condensable) 0.0048 FALSE 4078 W3PM 2009

W3Port 1 PM (Filterable) 0.0018 FALSE 4078 W3PM 2009

W3Port 1 PM (Condensable) 0.0112 FALSE 4078 W3PM 2009

W3Port 2 PM (Filterable) 0.0018 FALSE 4078 W3PM 2009

W3Port 2 PM (Condensable) 0.0111 FALSE 4078 W3PM 2009

W3Port 3 PM (Filterable) 0.0011 FALSE 4078 W3PM 2009

W3Port 3 PM (Condensable) 0.0015 FALSE 4078 W1 Hg 2006

W1 Port 1 Total Mercury (Hgt) 7.81 mi crogram per dry standard cubic meter ( FALSE 4072 P3 Hg 2006

CS34 Port 1 Total Mercury (Hgt) 5.96 mi crogram per dry standard cubic meter ( FALSE 4072 P3 Hg 2006

CS34 Port 2 Total Mercury (Hgt) 5.81 mi crogram per dry standard cubic meter ( FALSE 4072 P3 Hg 2006

CS34 Port 3 Total Mercury (Hgt) 6.92 mi crogram per dry standard cubic meter ( FALSE 4072 P5 Hg 2006

CS56 Port 1 Total Mercury (Hgt) 10.04 mi crogram per dry standard cubic meter ( FALSE 4072 P5 Hg 2006

CS56 Port 2 Total Mercury (Hgt) 9.24 mi crogram per dry standard cubic meter ( FALSE 4072 P4 Hg 2006

CS34 Port 1 Total Mercury (Hgt) 5.96 mi crogram per dry standard cubic meter ( FALSE 4072 P4 Hg 2006

CS34 Port 2 Total Mercury (Hgt) 5.81 mi crogram per dry standard cubic meter ( FALSE 4072 P4 Hg 2006

CS34 Port 3 Total Mercury (Hgt) 6.92 mi crogram per dry standard cubic meter ( FALSE 4078 W1 Hg 2006

W1 Port 2 Total Mercury (Hgt) 7.66 mi crogram per dry standard cubic meter ( FALSE 4078 W1 Hg 2006

W1 Port 3 Total Mercury (Hgt) 7.96 mi crogram per dry standard cubic meter ( FALSE 4078 W2 Hg 2006

W2 Port 1 Total Mercury (Hgt) 8.37 mi crogram per dry standard cubic meter ( FALSE 4078 W2 Hg 2006

W2 Port 2 Total Mercury (Hgt) 6.52 mi crogram per dry standard cubic meter ( FALSE 4078 W2 Hg 2006

W2 Port 3 Total Mercury (Hgt) 8.55 mi crogram per dry standard cubic meter ( FALSE 4078 W3Hg 2006

W3Port 1 Total Mercury (Hgt) 9.03 mi crogram per dry standard cubic meter ( FALSE 4078 W3Hg 2006

W3Port 2 Total Mercury (Hgt) 9.94 mi crogram per dry standard cubic meter ( FALSE 4078 W3Hg 2006

W3Port 3 Total Mercury (Hgt) 9.39 mi crogram per dry standard cubic meter ( FALSE 4078 W4 PM M5B 2008

W4 Port 1 PM (Filterable) 0.0022 FALSE 4078 W4 PM M5B 2008

W4 Port 1 PM (Condensable) 0.0023 FALSE 4078 W4 PM M5B 2008

W4 Port 2 PM (Filterable) 0.0053 FALSE 4078 W4 PM M5B 2008

W4 Port 2 PM (Condensable) 0.0022 FALSE 4078 W4 PM M5B 2008

W4 Port 3 PM (Filterable) 0.0047 FALSE 4078 W4 PM M5B 2008

W4 Port 3 PM (Condensable) 0.0018 FALSE 4078 W4 PM M201A 2008

W4 Port 1 PM10 (Filterable) 0.0005 FALSE 4078 W4 PM M201A 2008

W4 Port 1 PM (Condensable) 0.0083 FALSE 4078 W4 PM M201A 2008

W4 Port 2 PM10 (Filterable) 0.0005 FALSE 4078 W4 PM M201A 2008

W4 Port 2 PM (Condensable) 0.0053 FALSE 4078 W4 PM M201A 2008

W4 Port 3 PM10 (Filterable) 0.00067 FALSE 4078 W4 PM M201A 2008

W4 Port 3 PM (Condensable) 0.0066 FALSE 4078 W4 Metals 2008

W4 Port 1 Beryllium (Be) 0.2 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Metals 2008

W4 Port 1 Lead (Pb) 2.855 mi crogram per dry standard cubic meter ( FALSE 4078 W4 CO 2008

W4 Port 1 Carbon Monoxide (CO) 29.4 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 1 Sulfur Dioxide (SO2) 22.1 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 1 Nitrogen Oxide (NOx) 33.2 parts per million by volum e (dry) (ppmvd @ 7% O2) FALSE 4078 W4 CO 2008

W4 Port 2 Carbon Monoxide (CO) 45.9 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 2 Sulfur Dioxide (SO2) 23.6 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 2 Nitrogen Oxide (NOx) 33.6 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 3 Carbon Monoxide (CO) 31.9 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 3 Sulfur Dioxide (SO2) 23.2 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 CO 2008

W4 Port 3 Nitrogen Oxide (NOx) 33.9 parts per million by volum e (dry) (ppmvd) FALSE 4078 W4 HCl 2008

W4 Port 1 Hydrogen Chloride (HCl) 71.6 mi crogram per dry standard cubic meter ( FALSE 4078 W4 HCl 2008

W4 Port 2 Hydrogen Chloride (HCl) 142.4 mi crogram per dry standard cubic meter ( FALSE

Page 92sampling_run_pollutants1

4078 W4 HCl 2008

W4 Port 3 Hydrogen Chloride (HCl) 38.8 mi crogram per dry standard cubic meter ( FALSE 4078 W4 M13B Fluoride

W4 Port 1 Hydrogen Fluoride (HF) 38.7 mi crogram per dry standard cubic meter ( FALSE 4078 W4 M13B Fluoride

W4 Port 2 Hydrogen Fluoride (HF) 38.9 mi crogram per dry standard cubic meter ( FALSE 4078 W4 M13B Fluoride

W4 Port 3 Hydrogen Fluoride (HF) 38.6 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 7-2009

W4 Port 1 Total Mercury (Hgt) 2.35 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 7-2009

W4 Port 2 Total Mercury (Hgt) 1.73 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 7-2009

W4 Port 3 Total Mercury (Hgt) 1.75 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 1-2009

W4 Port 1 Total Mercury (Hgt) 1.17 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 1-2009

W4 Port 2 Total Mercury (Hgt) 1.14 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 1-2009

W4 Port 3 Total Mercury (Hgt) 0.97 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 7-2008

W4 Port 1 Total Mercury (Hgt) 1.3 mi crogram per dry

standard cubic meter ( FALSE 4078 W4 Hg 7-2008

W4 Port 2 Total Mercury (Hgt) 1.46 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Hg 7-2008

W4 Port 3 Total Mercury (Hgt) 1.48 mi crogram per dry standard cubic meter ( FALSE 4072 P6 Hg 2006

CS56 Port 3 Total Mercury (Hgt) 10.19 mi crogram per dry standard cubic meter ( FALSE 4072 P8 Hg 2006

P8 Port 2 Total Mercury (Hgt) 8.08 mi crogram per dry standard cubic meter ( FALSE 4072 P8 Hg 2006

P8 Port 3 Total Mercury (Hgt) 7.48 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Metals 2008

W4 Port 2 Beryllium (Be) 0.199 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Metals 2008

W4 Port 2 Lead (Pb) 2.196 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Metals 2008

W4 Port 3 Beryllium (Be) 0.199 mi crogram per dry standard cubic meter ( FALSE 4078 W4 Metals 2008

W4 Port 3 Lead (Pb) 0.916 mi crogram per dry standard cubic meter ( FALSE

Page 93sampling_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 0.00541 pound per hour (lb/hr)

FALSE 8.97 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00729 pound per hour (lb/hr)

FALSE 8.79 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0066 pound per hour (lb/hr)

FALSE 8.06 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 8.68 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr data not included in test report FALSE 8.42 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr values not included in test report. FALSE 8.62 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr data not included in test report. FALSE 7.4 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr data not included in test report. 29.7 pound per hour (lb/hr)

FALSE 0.022 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 37.3 pound per hour (lb/hr)

FALSE 0.027 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 23.3 pound per hour (lb/hr)

FALSE 0.017 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 40 pound per hour (lb/hr)

FALSE 0.03 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 26.2 pound per hour (lb/hr)

FALSE 0.02 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 49.8 pound per hour (lb/hr)

FALSE 0.037 pound per million British Thermal Unit (lb/MMBtu) FALSE oncentration = gr/dscf 15.9 pound per hour (lb/hr)

FALSE 0.02 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 19.2 pound per hour (lb/hr)

FALSE 0.024 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 14.5 pound per hour (lb/hr)

FALSE 0.018 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 18.2 pound per hour (lb/hr)

FALSE 0.023 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 13.4 pound per hour (lb/hr)

FALSE 0.017 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 18.1 pound per hour (lb/hr)

FALSE 0.023 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 17.8 pound per hour (lb/hr)

FALSE 0.014 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 28.8 pound per hour (lb/hr)

FALSE 0.022 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 18.7 pound per hour (lb/hr)

FALSE 0.015 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 29.6 pound per hour (lb/hr)

FALSE 0.023 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 16.8 pound per hour (lb/hr)

FALSE 0.013 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 23 pound per hour (lb/hr)

FALSE 0.018 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 46.2 pound per hour (lb/hr)

FALSE 0.068 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 7.9 pound per hour (lb/hr)

FALSE 0.012 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 41.8 pound per hour (lb/hr)

FALSE 0.064 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 9.464 pound per hour (lb/hr)

FALSE 0.015 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 38.6 pound per hour (lb/hr)

FALSE 0.061 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 11 pound per hour (lb/hr)

FALSE 0.017 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 46.4 pound per hour (lb/hr)

FALSE 0.052 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 5.2 pound per hour (lb/hr)

FALSE 0.006 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 68.1 pound per hour (lb/hr)

FALSE 0.077 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 4 pound per hour (lb/hr)

FALSE 0.0045 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 62.5 pound per hour (lb/hr)

FALSE 0.073 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 3.7 pound per hour (lb/hr)

FALSE 0.004 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 25.6 pound per hour (lb/hr)

FALSE 0.008 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 55.5 pound per hour (lb/hr)

FALSE 0.017 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 39.9 pound per hour (lb/hr)

FALSE 0.011 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 119 pound per hour (lb/hr)

FALSE 0.034 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 37.99 pound per hour (lb/hr)

FALSE 0.011 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 57.9 pound per hour (lb/hr)

FALSE 0.017 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 23.8 pound per hour (lb/hr)

FALSE 0.04 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 3.8 pound per hour (lb/hr)

FALSE 0.006 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 22.8 pound per hour (lb/hr)

FALSE 0.04 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 17.3 pound per hour (lb/hr)

FALSE 0.03 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 20.3 pound per hour (lb/hr)

FALSE 0.035 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 11.4 pound per hour (lb/hr)

FALSE 0.02 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 26 pound per hour (lb/hr)

FALSE 0.034 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 2.8 pound per hour (lb/hr)

FALSE 0.004 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf

Page 94sampling_run_pollutants1

25.7 pound per hour (lb/hr)

FALSE 0.033 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 5.8 pound per hour (lb/hr)

FALSE 0.007 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 24.4 pound per hour (lb/hr)

FALSE 0.031 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 7.6 pound per hour (lb/hr)

FALSE 0.01 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 11.7 pound per hour (lb/hr)

FALSE 0.003 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 72.3 pound per hour (lb/hr)

FALSE 0.021 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 11.8 pound per hour (lb/hr)

FALSE 0.003 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 73.9 pound per hour (lb/hr)

FALSE 0.021 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 7.3 pound per hour (lb/hr)

FALSE 0.002 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf 10.1 pound per hour (lb/hr)

FALSE 0.0028 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration = gr/dscf FALSE 6.69 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported 0.00148 pound per hour (lb/hr)

FALSE 5.8 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00136 pound per hour (lb/hr)

FALSE 5.37 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00168 pound per hour (lb/hr)

FALSE 6.48 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00541 pound per hour (lb/hr)

FALSE 8.79 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0049 pound per hour (lb/hr)

FALSE 8.06 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00148 pound per hour (lb/hr)

FALSE 5.8 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00162 pound per hour (lb/hr)

FALSE 5.37 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00201 pound per hour (lb/hr)

FALSE 6.48 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 6.63 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 6.78 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 8.19 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 7.09 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 6.92 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 6.98 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 7.6 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported FALSE 7.55 pound per trillion British Thermal Unit (lb/1012Btu) FALSE lb/hr not reported 18.9 pound per hour (lb/hr)

FALSE 0 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 19.7 pound per hour (lb/hr)

FALSE 0 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 46.8 pound per hour (lb/hr)

FALSE 0.01 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 19.4 pound per hour (lb/hr)

FALSE 0 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 41.2 pound per hour (lb/hr)

FALSE 0.01 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 15.76 pound per hour (lb/hr)

FALSE 0 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 4.9 pound per hour (lb/hr)

FALSE 0.001 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 81.8 pound per hour (lb/hr)

FALSE 0.015 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 5.1 pound per hour (lb/hr)

FALSE 0.001 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 53.8 pound per hour (lb/hr)

FALSE 0.009 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 5.6 pound per hour (lb/hr)

FALSE 0.0001 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 66.6 pound per hour (lb/hr)

FALSE 0.012 pound per million British Thermal Unit (lb/MMBtu) FALSE gr/dscf 0.00079 pound per hour (lb/hr)

FALSE 0.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.01 pound per hour (lb/hr)

FALSE 2.22 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0.03 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.04 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.03 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.05 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.28 pound per hour (lb/hr)

FALSE 0.0001 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.58 pound per hour (lb/hr)

FALSE 0.0001 pound per million British Thermal Unit (lb/MMBtu) FALSE

Page 95sampling_run_pollutants1

0.15 pound per hour (lb/hr)

FALSE 0.00003 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.16 pound per hour (lb/hr)

FALSE 0.000031 pound per million British Thermal Unit (lb/MMBtu) FALSE as total fluorides 0.15 pound per hour (lb/hr)

FALSE 0.000031 pound per million British Thermal Unit (lb/MMBtu) FALSE As total fluorides. 0.15 pound per hour (lb/hr)

FALSE 0.000031 pound per million British Thermal Unit (lb/MMBtu) FALSE Reported as total flourides FALSE 2.03 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1.5 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1.55 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0.95 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0.94 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0.79 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00729 pound per hour (lb/hr)

FALSE 8.97 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 6.78 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 6.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0008 pound per hour (lb/hr)

FALSE 0.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.01 pound per hour (lb/hr)

FALSE 1.71 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0008 pound per hour (lb/hr)

FALSE 0.2 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0 pound per hour (lb/hr)

FALSE 0.71 pound per trillion British Thermal Unit (lb/1012Btu) FALSE

Page 96sampling_run_pollutants1

run_pollutant_comment

lb/hr data not included in test report lb/hr values not included in test report. lb/hr data not included in test report. lb/hr data not included in test report. concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf oncentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf

Page 97sampling_run_pollutants1

concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf concentration = gr/dscf lb/hr not reported

lb/hr not reported lb/hr not reported lb/hr not reported lb/hr not reported lb/hr not reported lb/hr not reported lb/hr not reported lb/hr not reported

Page 98sampling_run_pollutants1

as total fluorides As total fluorides. Reported as total flourides

Page 99sampling_run_fuel

facility _id report_id sampling_port_id run_id fuel_pollutant fuel_conc fuel_conc_units fuel_conc_ND

fuel_conc_MDL 4072 P3 Hg 2006

CS34 Port 1 Chloride (Cl) 33 parts per million (dry) (ppm) FALSE 4072 P3 Hg 2006

CS34 Port 1 Mercury (Hg) 0.119 parts per million (dry) (ppm) FALSE 4072 P3 Hg 2006

CS34 Port 2 Chloride (Cl) 32 parts per million (dry) (ppm) FALSE 4072 P3 Hg 2006

CS34 Port 2 Mercury (Hg) 0.091 parts per million (dry) (ppm) FALSE 4072 P3 Hg 2006

CS34 Port 3 Chloride (Cl) 37 parts per million (dry) (ppm) FALSE 4072 P3 Hg 2006

CS34 Port 3 Mercury (Hg) 0.11 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 1 Chloride (Cl) 33 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 1 Mercury (Hg) 0.119 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 2 Chloride (Cl) 32 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 2 Mercury (Hg) 0.091 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 3 Chloride (Cl) 37 parts per million (dry) (ppm) FALSE 4072 P4 Hg 2006

CS34 Port 3 Mercury (Hg) 0.11 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 1 Chloride (Cl) 48 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 1 Mercury (Hg) 0.09 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 2 Chloride (Cl) 30 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 2 Mercury (Hg) 0.097 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 3 Chloride (Cl) 26 parts per million (dry) (ppm) FALSE 4072 P5 Hg 2006

CS56 Port 3 Mercury (Hg) 0.1 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 1 Chloride (Cl) 48 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 1 Mercury (Hg) 0.09 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 2 Chloride (Cl) 30 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 2 Mercury (Hg) 0.097 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 3 Chloride (Cl) 26 parts per million (dry) (ppm) FALSE 4072 P6 Hg 2006

CS56 Port 3 Mercury (Hg) 0.1 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 1 Chloride (Cl) 26 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 1 Mercury (Hg) 0.096 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 2 Chloride (Cl) 23 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 2 Mercury (Hg) 0.098 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 3 Chloride (Cl) 19 parts per million (dry) (ppm) FALSE 4072 P7 Hg 2006

P7 Port 3 Mercury (Hg) 0.084 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 1 Chloride (Cl) 32 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 1 Mercury (Hg) 0.108 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 2 Chloride (Cl) 34 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 2 Mercury (Hg) 0.104 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 3 Chloride (Cl) 36 parts per million (dry) (ppm) FALSE 4072 P8 Hg 2006

P8 Port 3 Mercury (Hg) 0.103 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 1 Chloride (Cl) 21 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 1 Mercury (Hg) 0.081 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 2 Chloride (Cl) 23 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 2 Mercury (Hg) 0.085 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 3 Chloride (Cl) 19 parts per million (dry) (ppm) FALSE 4078 W1 Hg 2006

W1 Port 3 Mercury (Hg) 0.085 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 1 Chloride (Cl) 19 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 1 Mercury (Hg) 0.085 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 2 Chloride (Cl) 23 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 2 Mercury (Hg) 0.093 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 3 Chloride (Cl) 24 parts per million (dry) (ppm) FALSE 4078 W2 Hg 2006

W2 Port 3 Mercury (Hg) 0.087 parts per million (dry) (ppm) FALSE 4078 W3Hg 2006

W3Port 1 Chloride (Cl) 16 parts per million (dry) (ppm) FALSE 4078 W3Hg 2006

W3Port 1 Mercury (Hg) 0.071 parts per million (dry) (ppm) FALSE 4078 W3Hg 2006

W3Port 2 Chloride (Cl) 17 parts per million (dry) (ppm) FALSE

Page 100sampling_run_fuel

4078 W3Hg 2006

W3Port 2 Mercury (Hg) 0.07 parts per million (dry) (ppm) FALSE 4078 W3Hg 2006

W3Port 3 Chloride (Cl) 16 parts per million (dry) (ppm) FALSE 4078 W3Hg 2006

W3Port 3 Mercury (Hg) 0.075 parts per million (dry) (ppm) FALSE

Page 101sampling_run_fuel

fuel_conc_MDL

Page 102