Facility _Information

facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_type

legal_address

legal_city legal_state legal_zip 983 983 Indiana-Kentucky Electric Corporation Indiana-Kentucky

Electric Corporation legal owner P.O. Box 468 Piketon OH 45661 2876 2876 Ohio Valley Electric Corporation Ohio Valley

Electric Corporation legal owner P.O. Box 468 Piketon OH 45661

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 Clifty Creek1335 Clifty

Hollow Road Madison IN 47250 P.O. Box 97 Madison IN 47250 Kyger Creek

5758 State Route 7 North

Cheshire OH 45620 P.O. Box 372 Cheshire OH 45620

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

Page 3Facility _Information

ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note FALSE FALSE Quarterly deviation reports as well as annual compliance certification report are required. No RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f FALSE FALSE Quarterly and semiannual deviation reports as well as annual compliance certification report are required. No RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 4Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 5Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 6Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 7Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 8Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 9Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 10Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 11Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 12Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 13Facility _Information

RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stablilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f RE: Response of the Ohio Valley Electric Corporation (OVEC) to December 24, 2009 Information Collection Request (ICR), OMB Control No. 2060-0631Dear Mr. Tsirigotis:OVEC is providing the enclosed information (data responsive to Parts I & II of the ICR) electronically in the U.S. EPA Electronic Reporting Tool (ERT) in response to the subject ICR for the two electric generating facilities owned and operated by OVEC. The ICR was received at OVEC's System Office on January 4, 2010.Som e clarification of our responses is also provided below, and should be considered in conjunction with the information provided as part of the ERT. Specifically , we offer the following clarification to the information provided.Part I Questions 10-13 - No. 2 Fuel Oil is combusted during startup and stabilization periods.Part I Question 15 - Design parameters for the boilers are developed prior to the construction of a unit using assumed values for fuel characteristics and operating conditions, and are valid only f

Page 14facility _contacts

facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 983 2 Environm ental Affairs Director Donald T. Fulkerson

7402897254 dfulkers@ovec.com TRUE 2876 1 Environm ental Affairs Director Donald T. Fulkerson

7402897254 dfulkers@ovec.com TRUE

Page 15facility _coal_utilized

facility _id coal_type percentage_mass percentage_btu

synfuel_type

coal_note 983 bitum inous 27 35 983 subbituminous 73 65 2876 bitum inous 30 39 2876 subbituminous 70 61

Page 16facility _oil_utilized

facility _id oil_type percentage_volume percentage_btu

other_type 983 No.2 Fuel Oil (distillate) 99 99 983 other (specify) 1 1 Used Oil 2876 No.2 Fuel Oil (distillate) 99 99 2876 other (specify) 1 1 Used Oil

Page 17facility _other_materials

facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain 983 AOD W ater/Urea Solution

FALSE TRUE 62680 num ber/year Units are gallons/year. An informed answer can not be given until a proposed standard is issued and reviewed. 983 Boiler Cleaning Solution

FALSE TRUE 437100 num ber/year Units are gallons/year. An informed answer can not be given until a proposed standard is issued and reviewed. 983 Coal Dust Surfactant

FALSE TRUE 25095 num ber/year Units are gallons/year. This material is used as a product. 983 Deicing Agent

FALSE TRUE 950 num ber/year Units are gallons/year. This material is used as a product. 983 Floor Sweeping Com pound

FALSE TRUE 37.9 tons/year An informed answer can not be given until a proposed standard is issued and reviewed. 983 Hematite FALSE TRUE 2306.2 tons/year This material is used as a product. 983 Used Oil Dry FALSE TRUE 14 tons/year An informed answer can not be given until a proposed standard is issued and reviewed. 2876 Antifreeze FALSE TRUE 212 num ber/year Units are gallons/year. This material is used as a product. 2876 Boiler Cleaning Solution

FALSE TRUE 216000 num ber/year Units are gallons/year. An informed answer can not be given until a proposed standard is issued and reviewed. 2876 Coal Dust Surfactant

FALSE TRUE 155.4 tons/year This material is used as a product. 2876 Floor Sweeping Com pound

FALSE TRUE 7.175 tons/year An informed answer can not be given until a proposed standard is issued and reviewed. 2876 Magnetite FALSE TRUE 50.76 tons/year This material is used as a product. 2876 On-site STP Sand Filter Sludge

FALSE TRUE 0.3 tons/year An informed answer can not be given until a proposed standard is issued and reviewed. 2876 Used Oil Dry FALSE TRUE 14 tons/year An informed answer can not be given until a proposed standard is issued and reviewed.

Page 18facility _other_materials

rcra_explain An informed answer can not be given until a proposed standard is issued and reviewed. An informed answer can not be given until a proposed standard is issued and reviewed. This material is used as a product. This material is used as a product. An informed answer can not be given until a proposed standard is issued and reviewed. This material is used as a product. An informed answer can not be given until a proposed standard is issued and reviewed. This material is used as a product. An informed answer can not be given until a proposed standard is issued and reviewed. This material is used as a product. An informed answer can not be given until a proposed standard is issued and reviewed. This material is used as a product. An informed answer can not be given until a proposed standard is issued and reviewed. An informed answer can not be given until a proposed standard is issued and reviewed.

Page 19boiler_information

facility _id boiler_id boiler_type boiler_other bottom_design

design_fuel heat_input max_heat_input MW e_capacity 983 1 Wa ll firing - front firing We t Bottom coal 1869 215 983 2 Wa ll firing - front firing We t Bottom coal 1869 215 983 3 Wa ll firing - front firing We t Bottom coal 1869 215 983 4 Wa ll firing - front firing We t Bottom coal 1869 215 983 5 Wa ll firing - front firing We t Bottom coal 1869 215 983 6 Wa ll firing - front firing We t Bottom coal 1869 215 2876 1 Wa ll firing - front firing We t Bottom coal 1850 214 2876 2 Wa ll firing - front firing We t Bottom coal 1850 213 2876 3 Wa ll firing - front firing We t Bottom coal 1850 213 2876 4 Wa ll firing - front firing We t Bottom coal 1850 213 2876 5 Wa ll firing - front firing We t Bottom coal 1850 213

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 199 88.8 2075 1995 1050 1001 FALSE 1050 199 88.8 2075 1998 1050 1018 FALSE 1050 199 88.8 2075 1993 1050 1011 FALSE 1050 199 88.8 2075 1998 1050 1018 FALSE 1050 199 88.8 2075 1995 1050 979 FALSE 1050 199 88.8 2075 1992 1050 1009 FALSE 1050 198 88.8 2075 2000 1050 1038 FALSE 1050 197 88.8 2075 1960 1050 1047 FALSE 1050 197 88.8 2075 1978 1050 1041 FALSE 1050 197 88.8 2075 1973 1050 1046 FALSE 1050 197 88.8 2075 2000 1050 1034 FALSE 1050

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 982 7166 75.6 N FALSE FALSE 998 7920 85.6 N FALSE FALSE 990 7025 75 N FALSE FALSE 1003 7481 79.2 N FALSE FALSE 999 7661 81.9 N FALSE FALSE 975 7528 76.5 N FALSE FALSE 1020 7386 77 N FALSE FALSE 1029 7172 74 N FALSE FALSE 1017 7350 77.5 N FALSE FALSE 1025 7668 78.6 N FALSE FALSE 1025 7921 83.4 N FALSE

Page 22boiler_information

NOx_control

SO2_control

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

Page 23boiler_fuels

facility _id boiler_id fuel_type fuel_year percentage_massvol percentage_btu

other_type 983 1 coal - bituminous 2009 26 35 983 1 coal - subbituminous 2009 74 65 983 1 oil - distillate 2009 0 0 983 1 oil - residual or bunker 2009 0 0 983 2 coal - bituminous 2009 26 35 983 2 coal - subbituminous 2009 74 65 983 2 oil - distillate 2009 0 0 983 2 oil - residual or bunker 2009 0 0 983 3 coal - bituminous 2009 26 35 983 3 coal - subbituminous 2009 74 65 983 3 oil - distillate 2009 0 0 983 3 oil - residual or bunker 2009 0 0 983 4 coal - bituminous 2009 27 35 983 4 coal - subbituminous 2009 73 65 983 4 oil - distillate 2009 0 0 983 4 oil - residual or bunker 2009 0 0 983 5 coal - bituminous 2009 27 35 983 5 coal - subbituminous 2009 73 65 983 5 oil - distillate 2009 0 0 983 5 oil - residual or bunker 2009 0 0 983 6 coal - bituminous 2009 27 35 983 6 coal - subbituminous 2009 73 65 983 6 oil - distillate 2009 0 0 983 6 oil - residual or bunker 2009 0 0 2876 1 coal - bituminous 2009 30 39 2876 1 coal - subbituminous 2009 70 61 2876 1 oil - distillate 2009 0 0 2876 1 oil - residual or bunker 2009 0 0 2876 2 coal - bituminous 2009 30 39 2876 2 coal - subbituminous 2009 70 61 2876 2 oil - distillate 2009 0 0 2876 3 coal - bituminous 2009 30 39 2876 3 coal - subbituminous 2009 70 61 2876 3 oil - distillate 2009 0 0 2876 4 coal - bituminous 2009 30 39 2876 4 coal - subbituminous 2009 70 61 2876 4 oil - distillate 2009 0 0 2876 5 coal - bituminous 2009 30 39 2876 5 coal - subbituminous 2009 70 61 2876 5 oil - distillate 2009 0 0

Page 24boiler_control_NOx

facility _id boiler_id NOx_type NOx_other NOx_online 983 1 Overfire Air 3/1/1999 983 2 Overfire Air 10/1/1999 983 3 Overfire Air 2/1/1999 983 4 Overfire Air 11/1/1998 983 5 Overfire Air 10/1/1998 983 6 Overfire Air 5/1/1998 2876 1 Overfire Air 11/1/1998 2876 2 Overfire Air 6/1/1998 2876 3 Overfire Air 11/1/1999 2876 4 Overfire Air 2/1/1999 2876 5 Overfire Air 10/1/1995

Page 25boiler_control_SO2

facility _id boiler_id SO2_type SO2_other SO2_online 983 1 Low Sulfur Coal 1/1/1995 983 1 Physical Coal Cleaning 2/1/1955 983 2 Low Sulfur Coal 1/1/1995 983 2 Physical Coal Cleaning 5/1/1955 983 3 Low Sulfur Coal 1/1/1995 983 3 Physical Coal Cleaning 7/1/1955 983 4 Low Sulfur Coal 1/1/1995 983 4 Physical Coal Cleaning 10/1/1955 983 5 Low Sulfur Coal 1/1/1995 983 5 Physical Coal Cleaning 11/1/1955 983 6 Low Sulfur Coal 1/1/1995 983 6 Physical Coal Cleaning 3/1/1956 2876 1 Low Sulfur Coal 1/1/1995 2876 1 Physical Coal Cleaning 2/1/1955 2876 2 Low Sulfur Coal 1/1/1995 2876 2 Physical Coal Cleaning 6/1/1955 2876 3 Low Sulfur Coal 1/1/1995 2876 3 Physical Coal Cleaning 9/1/1955 2876 4 Low Sulfur Coal 1/1/1995 2876 4 Physical Coal Cleaning 11/1/1955 2876 5 Low Sulfur Coal 1/1/1995 2876 5 Physical Coal Cleaning 12/1/1955

Page 26boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online

Page 27facility _units

facility _id unit_id 983 1 983 2 983 3 983 4 983 5 983 6 2876 1 2876 2 2876 3 2876 4 2876 5

Page 28unit_boilers

facility _id unit_id boiler_id 983 1 1 983 2 2 983 3 3 983 4 4 983 5 5 983 6 6 2876 1 1 2876 2 2 2876 3 3 2876 4 4 2876 5 5

Page 29facility _controls

facility _id control_id control_group control_type

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 983 ESP1 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 8/1/1979 983 ESP2 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 6/1/1979 983 ESP3 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 4/1/1979 983 ESP4 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 3/1/1979 983 ESP5 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 12/1/1978 983 ESP6 PM control Electrostatic precipitator, hot side, w/ flue gas conditioning FALSE 9/1/1977 983 SCR1 NOx control Selective Cataly

tic Reduction FALSE 7/1/2003 Urea to Ammonia conversion 983 SCR2 NOx control Selective Cataly

tic Reduction FALSE 4/1/2003 Urea to Ammonia conversion 983 SCR3 NOx control Selective Cataly

tic Reduction FALSE 6/1/2003 Urea to Ammonia conversion 983 SCR4 NOx control Selective Cataly

tic Reduction FALSE 1/1/2003 Urea to Ammonia conversion 983 SCR5 NOx control Selective Cataly

tic Reduction FALSE 11/1/2002 Urea to Ammonia conversion 2876 ESP1 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 6/1/1980 2876 ESP2 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 4/1/1980 2876 ESP3 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 2/1/1980 2876 ESP4 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 3/1/1980 2876 ESP5 PM control Electrostatic precipitator, cold side, w/ flue gas conditioning FALSE 5/1/1980 2876 SCR1 NOx control Selective Cataly

tic Reduction FALSE 10/1/2002 Urea to Ammonia conversion 2876 SCR2 NOx control Selective Cataly

tic Reduction FALSE 12/1/2002 Urea to Ammonia conversion 2876 SCR3 NOx control Selective Cataly

tic Reduction FALSE 2/1/2003 Urea to Ammonia conversion 2876 SCR4 NOx control Selective Cataly

tic Reduction FALSE 4/1/2003 Urea to Ammonia conversion 2876 SCR5 NOx control Selective Cataly

tic Reduction FALSE 6/1/2003 Urea to Ammonia conversion

Page 30facility _controls

reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive

Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion

Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion Urea to Ammonia conversion

Page 31facility _sampling_ports

facility _id sampling_port_id 983 COMMON STACK 1 983 COMMON STACK 2 983 UNIT 1 DUCT 983 UNIT 2 DUCT 983 UNIT 3 DUCT 983 UNIT 4 DUCT 983 UNIT 5 DUCT 983 UNIT 6 DUCT 2876 COMMON STACK 2876 UNIT 1 DUCT 2876 UNIT 2 DUCT 2876 UNIT 3 DUCT 2876 UNIT 4 DUCT 2876 UNIT 5 DUCT

Page 32facility _stacks

facility _id stack_id stack_height stack_diameter

sack_gas_velocity 983 CS001 983 22.75 983 CS002 983 22.75 2876 CS001 1000 29.33

Page 33configurations

facility _id configuration_id 983 Unit 1 983 Unit 2 983 Unit 3 983 Unit 4 983 Unit 5 983 Unit 6 2876 Unit 1 2876 Unit 2 2876 Unit 3 2876 Unit 4 2876 Unit 5

Page 34configuration_components

facility _id configuration_id

component_id

order component_type port_near 983 Unit 1 1 1 Unit 983 Unit 1 COMMON STACK 1 5 Sam pling Port next 983 Unit 1 CS001 6 Stack 983 Unit 1 ESP1 3 PM control 983 Unit 1 SCR1 2 NOx control 983 Unit 1 UNIT 1 DUCT 4 Sam pling Port pevious 983 Unit 2 2 1 Unit 983 Unit 2 COMMON STACK 1 5 Sam pling Port next 983 Unit 2 CS001 6 Stack 983 Unit 2 ESP2 3 PM control 983 Unit 2 SCR2 2 NOx control 983 Unit 2 UNIT 2 DUCT 4 Sam pling Port pevious 983 Unit 3 3 1 Unit 983 Unit 3 COMMON STACK 1 5 Sam pling Port next 983 Unit 3 CS001 6 Stack 983 Unit 3 ESP3 3 PM control 983 Unit 3 SCR3 2 NOx control 983 Unit 3 UNIT 3 DUCT 4 Sam pling Port pevious 983 Unit 4 4 1 Unit 983 Unit 4 COMMON STACK 2 5 Sam pling Port next 983 Unit 4 CS002 6 Stack 983 Unit 4 ESP4 3 PM control 983 Unit 4 SCR4 2 NOx control 983 Unit 4 UNIT 4 DUCT 4 Sam pling Port pevious 983 Unit 5 5 1 Unit 983 Unit 5 COMMON STACK 2 5 Sam pling Port next 983 Unit 5 CS002 6 Stack 983 Unit 5 ESP5 3 PM control 983 Unit 5 SCR5 2 NOx control 983 Unit 5 UNIT 5 DUCT 4 Sam pling Port pevious 983 Unit 6 6 1 Unit 983 Unit 6 COMMON STACK 2 4 Sam pling Port next 983 Unit 6 CS002 5 Stack 983 Unit 6 ESP6 2 PM control 983 Unit 6 UNIT 6 DUCT 3 Sam pling Port pevious 2876 Unit 1 1 1 Unit 2876 Unit 1 COMMON STACK 5 Sam pling Port next 2876 Unit 1 CS001 6 Stack 2876 Unit 1 ESP1 3 PM control 2876 Unit 1 SCR1 2 NOx control 2876 Unit 1 UNIT 1 DUCT 4 Sam pling Port pevious 2876 Unit 2 2 1 Unit 2876 Unit 2 COMMON STACK 5 Sam pling Port next 2876 Unit 2 CS001 6 Stack 2876 Unit 2 ESP2 3 PM control 2876 Unit 2 SCR2 2 NOx control 2876 Unit 2 UNIT 2 DUCT 4 Sam pling Port pevious 2876 Unit 3 3 1 Unit 2876 Unit 3 COMMON STACK 5 Sam pling Port next 2876 Unit 3 CS001 6 Stack 2876 Unit 3 ESP3 3 PM control

Page 35configuration_components

2876 Unit 3 SCR3 2 NOx control 2876 Unit 3 UNIT 3 DUCT 4 Sam pling Port pevious 2876 Unit 4 4 1 Unit 2876 Unit 4 COMMON STACK 5 Sam pling Port next 2876 Unit 4 CS001 6 Stack 2876 Unit 4 ESP4 3 PM control 2876 Unit 4 SCR4 2 NOx control 2876 Unit 4 UNIT 4 DUCT 4 Sam pling Port pevious 2876 Unit 5 5 1 Unit 2876 Unit 5 COMMON STACK 5 Sam pling Port next 2876 Unit 5 CS001 6 Stack 2876 Unit 5 ESP5 3 PM control 2876 Unit 5 SCR5 2 NOx control 2876 Unit 5 UNIT 5 DUCT 4 Sam pling Port pevious

Page 36configuration_pollutants1

facility _id configuration_id

pollutant_nam e

permit_type_1

em lim it_1 em lim it_units_1 avg_period_1

em lim it_2 em lim it_units_2 2876 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 2876 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 12.3 pound per million British Thermal Unit (lb/MMBtu) 2876 Unit 2 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 2876 Unit 2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 12.3 pound per million British Thermal Unit (lb/MMBtu) 2876 Unit 3 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 2876 Unit 3 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 12.3 pound per million British Thermal Unit (lb/MMBtu) 2876 Unit 4 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 2876 Unit 4 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 12.3 pound per million British Thermal Unit (lb/MMBtu) 2876 Unit 5 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 2876 Unit 5 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 12.3 pound per million British Thermal Unit (lb/MMBtu) 983 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 983 Unit 2 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 983 Unit 3 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 3 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 983 Unit 4 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 4 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 983 Unit 5 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 5 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days 983 Unit 6 PM (Filterable) Fderal - Title V Operating Permit

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

3 hours 983 Unit 6 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

30 days

Page 37configuration_pollutants1

avg_period_2

em lim it_3 em lim it_units_3 avg_period_3

em lim it_4 em lim it_units_4 avg_period_4

em lim it_details

test_method Method 5 24 hours 1.2 pound per million British Thermal Unit (lb/MMBtu) 30 days The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Method 5 24 hours 1.2 pound per million British Thermal Unit (lb/MMBtu) 30 days The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Method 5 24 hours 1.2 pound per million British Thermal Unit (lb/MMBtu) 30 days The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Method 5 24 hours 1.2 pound per million British Thermal Unit (lb/MMBtu) 30 days The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Method 5 24 hours 1.2 pound per million British Thermal Unit (lb/MMBtu) 30 days The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Method 5

Method 5

Method 5

Method 5

Method 5

Method 5

Page 38configuration_pollutants1

em rate em rate_units guarantee_level

_explain

req_monitoring

eq_recordkeeping

req_reporting Yes Originally

99.39% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing twice during term of the permit. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system, and maintain daily records of the actual heat input values. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

99.39% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in acordance with 40 CFR Part 60. Conduct particulate emission testing twice during term of the permit. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in acordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system, and maintain daily records of the actual heat input values. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

99.39% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing twice during term of the permit. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system, and maintain daily records of the actual heat input values. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

99.39% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing twice during term of the permit. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system, and maintain daily records of the actual heat input values. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

99.39% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing twice during term of the permit. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. The emission limit of 1.2 lb/mmBTU will become effective once construction of the FGD System is completed and the unit emits out the new replacement stack. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system, and maintain daily records of the actual heat input values. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

98.41% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are appplicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

98.41% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

98.41% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

98.41% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

98.41% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Yes Originally

99.7% ESP Removal Efficiency . No other guaranteed emission rates are applicable. Continuously

monitor and record opacity in accordance with 40 CFR Part 60. Conduct particulate emission testing on a biennial basis. Maintain records of % opacity on a 6-minute block average basis as well as results of daily calibration checks. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Yes No guaranteed emission rates are applicable. However, the new FGD System will be guaranteed to remove 98.0% of SO2 for a period of not less than two years. Continuously

monitor and record SO2 emissions in accordance with 40 CFR Part 75. Maintain records of the average daily and rolling 30-day

average emission rates as well as results of daily calibration checks of the CEMS system. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime.

Page 39configuration_pollutants1

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime.

Page 40configuration_pollutants1

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime. Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test. Quarterly

reports documenting information of all instances of values in excess of the rolling 30-day average emission rate limit as well as any SO2 CEMS monitoring system downtime.

Page 41configuration_pollutants1

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 20% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 30 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Quarterly

reports documenting information of all instances of opacity values in excess of the 40% limit as well as any monitoring system downtime. W ritten reports of the particulate emission tests are to be submitted within 45 days following completion of the test.

Page 42control_technologies

facility _id configuration_id

component_id

control_id project_title project_type vendor_name

vndor_contact

vendor_phone

Page 43control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive

Page 44control_technologies

injection_point

HAP_em ission_reduction

HAP_em ission_rate

HAP_em ission_rate_units

HAP_achieved_reduction

HAP_achieved_rate

HAP_achieved_rate_units

feed_rate feed_rate_units

Page 45control_technologies

feed_rate_units

Page 46control_coal_ranks

facility _id configuration_id

component_id

control_id coal_type

Page 47control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e

Page 48control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year

Page 49control_costs

CBI

Page 50mi sc_controls

facility _id mi sc_control_id

control_description

Page 51mi sc_control_configurations

facility _id mi sc_control_id

configuration_id

Page 52fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_type state_country other_country

county 983 AprilAlicia#2 4/1/2009 40236 short tons (2000 lbs) coal PA PA - Greene 983 AprilCora 4/1/2009 191599 short tons (2000 lbs) coal WY WY - Campbell 983 AprilFederal 4/1/2009 22254 short tons (2000 lbs) coal WV WV- Monongalia 983 AprilRhino 4/1/2009 48906 short tons (2000 lbs) coal KY KY - Letcher 983 AugRhino 8/1/2009 49696 short tons (2000 lbs) coal KY KY - Letcher 983 AugustAlicia#2

8/1/2009 54948 short tons (2000 lbs) coal PA PA - Greene 983 AugustCora 8/1/2009 173902 short tons (2000 lbs) coal WY WY - Campbell 983 DecAlicia#2 12/1/2009 47619 short tons (2000 lbs) coal PA PA - Greene 983 DecCora 12/1/2009 250900 short tons (2000 lbs) coal WY WY - Campbell 983 DecFederal 12/1/2009 18343 short tons (2000 lbs) coal WV WV- Monongalia 983 DecRhino 12/1/2009 32059 short tons (2000 lbs) coal KY KY - Letcher 983 FebAlicia#2 2/1/2009 32121 short tons (2000 lbs) coal PA PA - Greene 983 FebRhino 2/1/2009 36706 short tons (2000 lbs) coal KY KY - Letcher 983 FebruaryCora

2/1/2009 154387 short tons (2000 lbs) coal WY WY - Campbell 983 February Federal

2/1/2009 56838 short tons (2000 lbs) coal WV WV- Monongalia 983 JanRhino 1/1/2009 24932 short tons (2000 lbs) coal KY KY - Letcher 983 January

Alicia#2 1/1/2009 9033 short tons (2000 lbs) coal PA PA - Greene 983 JanuaryCora 1/1/2009 247247 short tons (2000 lbs) coal WY WY - Campbell 983 January Federal

1/1/2009 45335 short tons (2000 lbs) coal WV WV- Monongalia 983 July Alicia#2 7/1/2009 99809 short tons (2000 lbs) coal PA PA - Greene 983 JulyCora 7/1/2009 211750 short tons (2000 lbs) coal WY WY - Campbell 983 July Federal 7/1/2009 12206 short tons (2000 lbs) coal WV WV- Monongalia 983 July Rhino 7/1/2009 19151 short tons (2000 lbs) coal KY KY - Letcher 983 JuneAlicia#2 6/1/2009 24870 short tons (2000 lbs) coal PA PA - Greene 983 JuneCora 6/1/2009 153106 short tons (2000 lbs) coal WY WY - Campbell 983 JuneFederal 6/1/2009 23419 short tons (2000 lbs) coal WV WV- Monongalia 983 JuneRhino 6/1/2009 54140 short tons (2000 lbs) coal KY KY - Letcher 983 MarchAlicia#2

3/1/2009 21164 short tons (2000 lbs) coal PA PA - Greene 983 MarchCora 3/1/2009 205703 short tons (2000 lbs) coal WY WY - Campbell 983 MarchFederal

3/1/2009 15330 short tons (2000 lbs) coal WV WV- Monongalia 983 MarchRhino 3/1/2009 39805 short tons (2000 lbs) coal KY KY - Letcher 983 May Alicia#2 5/1/2009 42965 short tons (2000 lbs) coal PA PA - Greene 983 MayCora 5/1/2009 181428 short tons (2000 lbs) coal WY WY - Campbell 983 May Federal 5/1/2009 33018 short tons (2000 lbs) coal WV WV- Monongalia 983 May Rhino 5/1/2009 50673 short tons (2000 lbs) coal KY KY - Letcher 983 NovAlicia#2 11/1/2009 65451 short tons (2000 lbs) coal PA PA - Greene 983 NovCora 11/1/2009 249932 short tons (2000 lbs) coal WY WY - Campbell 983 NovFederal 11/1/2009 4437 short tons (2000 lbs) coal WV WV- Monongalia 983 NovRhino 11/1/2009 52444 short tons (2000 lbs) coal KY KY - Letcher 983 OctAlicia#2 10/1/2009 26408 short tons (2000 lbs) coal PA PA - Greene 983 OctCora 10/1/2009 265010 short tons (2000 lbs) coal WY WY - Campbell 983 OctFederal 10/1/2009 12239 short tons (2000 lbs) coal WV WV- Monongalia 983 OctRhino 10/1/2009 35730 short tons (2000 lbs) coal KY KY - Letcher 983 SeptAlicia#2 9/1/2009 72217 short tons (2000 lbs) coal PA PA - Greene 983 SeptCora 9/1/2009 205615 short tons (2000 lbs) coal WY WY - Campbell 983 SeptRhino 9/1/2009 29378 short tons (2000 lbs) coal KY KY - Letcher 2876 AprilCora 4/1/2009 128960 short tons (2000 lbs) coal WY WY - Campbell 2876 AprilEastern 4/1/2009 108870 short tons (2000 lbs) coal PA PA - Greene 2876 AugEastern 8/1/2009 65395 short tons (2000 lbs) coal PA PA - Greene 2876 AugustCora 8/1/2009 189566 short tons (2000 lbs) coal WY WY - Campbell 2876 DecEastern 12/1/2009 125486 short tons (2000 lbs) coal PA PA - Greene

Page 53fuel_shipments

2876 DecemberCora

12/1/2009 188769 short tons (2000 lbs) coal WY WY - Campbell 2876 FebEastern 2/1/2009 61031 short tons (2000 lbs) coal PA PA - Greene 2876 FebruaryCora

2/1/2009 147600 short tons (2000 lbs) coal WY WY - Campbell 2876 JanEastern 1/1/2009 64867 short tons (2000 lbs) coal PA PA - Greene 2876 JanuaryCora 1/1/2009 200608 short tons (2000 lbs) coal WY WY - Campbell 2876 JulyCora 7/1/2009 151981 short tons (2000 lbs) coal WY WY - Campbell 2876 July Eastern 7/1/2009 94127 short tons (2000 lbs) coal PA PA - Greene 2876 JuneCora 6/1/2009 127745 short tons (2000 lbs) coal WY WY - Campbell 2876 JuneEastern 6/1/2009 160481 short tons (2000 lbs) coal PA PA - Greene 2876 MarchCora 3/1/2009 170997 short tons (2000 lbs) coal WY WY - Campbell 2876 MarchEastern

3/1/2009 51163 short tons (2000 lbs) coal PA PA - Greene 2876 MayCora 5/1/2009 153355 short tons (2000 lbs) coal WY WY - Campbell 2876 May Eastern 5/1/2009 110189 short tons (2000 lbs) coal PA PA - Greene 2876 NovEastern 11/1/2009 92775 short tons (2000 lbs) coal PA PA - Greene 2876 Novem berCora

11/1/2009 131672 short tons (2000 lbs) coal WY WY - Campbell 2876 OctEastern 10/1/2009 52027 short tons (2000 lbs) coal PA PA - Greene 2876 OctoberCora

10/1/2009 160317 short tons (2000 lbs) coal WY WY - Campbell 2876 SeptEastern 9/1/2009 82732 short tons (2000 lbs) coal PA PA - Greene 2876 Septem berCora

9/1/2009 147779 short tons (2000 lbs) coal WY WY - Campbell

Page 54fuel_shipments

coal_seam shipment_method Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Pittsburgh No.8

Barge Elkhorn No.3

Barge Pittsburgh No.8

Barge WY - Campbell Barge Elkhorn No.3

Barge WY - Campbell Barge Pittsburgh No. 8

Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge

Page 55fuel_shipments

WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge Pittsburgh No. 8

Barge WY - Campbell Barge

Page 56fuel_shipment_configurations

facility _id shipment_id

configuration_id 983 AprilAlicia#2

Unit 1 983 AprilAlicia#2

Unit 2 983 AprilAlicia#2

Unit 3 983 AprilAlicia#2

Unit 4 983 AprilAlicia#2

Unit 5 983 AprilAlicia#2

Unit 6 983 AprilCora Unit 1 983 AprilCora Unit 2 983 AprilCora Unit 3 983 AprilCora Unit 4 983 AprilCora Unit 5 983 AprilCora Unit 6 983 AprilFederal

Unit 1 983 AprilFederal

Unit 2 983 AprilFederal

Unit 3 983 AprilFederal

Unit 4 983 AprilFederal

Unit 5 983 AprilFederal

Unit 6 983 AprilRhino Unit 1 983 AprilRhino Unit 2 983 AprilRhino Unit 3 983 AprilRhino Unit 4 983 AprilRhino Unit 5 983 AprilRhino Unit 6 983 AugRhino Unit 1 983 AugRhino Unit 2 983 AugRhino Unit 3 983 AugRhino Unit 4 983 AugRhino Unit 5 983 AugRhino Unit 6 983 AugustAlicia#2

Unit 1 983 AugustAlicia#2

Unit 2 983 AugustAlicia#2

Unit 3 983 AugustAlicia#2

Unit 4 983 AugustAlicia#2

Unit 5 983 AugustAlicia#2

Unit 6 983 AugustCora

Unit 1 983 AugustCora

Unit 2 983 AugustCora

Unit 3 983 AugustCora

Unit 4 983 AugustCora

Unit 5 983 AugustCora

Unit 6 983 DecAlicia#2

Unit 1 983 DecAlicia#2

Unit 2 983 DecAlicia#2

Unit 3 983 DecAlicia#2

Unit 4 983 DecAlicia#2

Unit 5 983 DecAlicia#2

Unit 6 983 DecCora Unit 1 983 DecCora Unit 2 983 DecCora Unit 3

Page 57fuel_shipment_configurations

983 DecCora Unit 4 983 DecCora Unit 5 983 DecCora Unit 6 983 DecFederal Unit 1 983 DecFederal Unit 2 983 DecFederal Unit 3 983 DecFederal Unit 4 983 DecFederal Unit 5 983 DecFederal Unit 6 983 DecRhino Unit 1 983 DecRhino Unit 2 983 DecRhino Unit 3 983 DecRhino Unit 4 983 DecRhino Unit 5 983 DecRhino Unit 6 983 FebAlicia#2

Unit 1 983 FebAlicia#2

Unit 2 983 FebAlicia#2

Unit 3 983 FebAlicia#2

Unit 4 983 FebAlicia#2

Unit 5 983 FebAlicia#2

Unit 6 983 FebRhino Unit 1 983 FebRhino Unit 2 983 FebRhino Unit 3 983 FebRhino Unit 4 983 FebRhino Unit 5 983 FebRhino Unit 6 983 FebruaryCora

Unit 1 983 FebruaryCora

Unit 2 983 FebruaryCora

Unit 3 983 FebruaryCora

Unit 4 983 FebruaryCora

Unit 5 983 FebruaryCora

Unit 6 983 February Federal

Unit 1 983 February Federal

Unit 2 983 February Federal

Unit 3 983 February Federal

Unit 4 983 February Federal

Unit 5 983 February Federal

Unit 6 983 JanRhino Unit 1 983 JanRhino Unit 2 983 JanRhino Unit 3 983 JanRhino Unit 4 983 JanRhino Unit 5 983 JanRhino Unit 6 983 January

Alicia#2 Unit 1 983 January

Alicia#2 Unit 2 983 January

Alicia#2 Unit 3 983 January

Alicia#2 Unit 4 983 January

Alicia#2 Unit 5 983 January

Alicia#2 Unit 6 983 JanuaryCora

Unit 1

Page 58fuel_shipment_configurations

983 JanuaryCora

Unit 2 983 JanuaryCora

Unit 3 983 JanuaryCora

Unit 4 983 JanuaryCora

Unit 5 983 JanuaryCora

Unit 6 983 January Federal

Unit 1 983 January Federal

Unit 2 983 January Federal

Unit 3 983 January Federal

Unit 4 983 January Federal

Unit 5 983 January Federal

Unit 6 983 July Alicia#2 Unit 1 983 July Alicia#2 Unit 2 983 July Alicia#2 Unit 3 983 July Alicia#2 Unit 4 983 July Alicia#2 Unit 5 983 July Alicia#2 Unit 6 983 JulyCora Unit 1 983 JulyCora Unit 2 983 JulyCora Unit 3 983 JulyCora Unit 4 983 JulyCora Unit 5 983 JulyCora Unit 6 983 July Federal Unit 1 983 July Federal Unit 2 983 July Federal Unit 3 983 July Federal Unit 4 983 July Federal Unit 5 983 July Federal Unit 6 983 July Rhino Unit 1 983 July Rhino Unit 2 983 July Rhino Unit 3 983 July Rhino Unit 4 983 July Rhino Unit 5 983 July Rhino Unit 6 983 JuneAlicia#2

Unit 1 983 JuneAlicia#2

Unit 2 983 JuneAlicia#2

Unit 3 983 JuneAlicia#2

Unit 4 983 JuneAlicia#2

Unit 5 983 JuneAlicia#2

Unit 6 983 JuneCora Unit 1 983 JuneCora Unit 2 983 JuneCora Unit 3 983 JuneCora Unit 4 983 JuneCora Unit 5 983 JuneCora Unit 6 983 JuneFederal

Unit 1 983 JuneFederal

Unit 2 983 JuneFederal

Unit 3 983 JuneFederal

Unit 4 983 JuneFederal

Unit 5

Page 59fuel_shipment_configurations

983 JuneFederal

Unit 6 983 JuneRhino Unit 1 983 JuneRhino Unit 2 983 JuneRhino Unit 3 983 JuneRhino Unit 4 983 JuneRhino Unit 5 983 JuneRhino Unit 6 983 MarchAlicia#2

Unit 1 983 MarchAlicia#2

Unit 2 983 MarchAlicia#2

Unit 3 983 MarchAlicia#2

Unit 4 983 MarchAlicia#2

Unit 5 983 MarchAlicia#2

Unit 6 983 MarchCora Unit 1 983 MarchCora Unit 2 983 MarchCora Unit 3 983 MarchCora Unit 4 983 MarchCora Unit 5 983 MarchCora Unit 6 983 MarchFederal

Unit 1 983 MarchFederal

Unit 2 983 MarchFederal

Unit 3 983 MarchFederal

Unit 4 983 MarchFederal

Unit 5 983 MarchFederal

Unit 6 983 MarchRhino

Unit 1 983 MarchRhino

Unit 2 983 MarchRhino

Unit 3 983 MarchRhino

Unit 4 983 MarchRhino

Unit 5 983 MarchRhino

Unit 6 983 May Alicia#2 Unit 1 983 May Alicia#2 Unit 2 983 May Alicia#2 Unit 3 983 May Alicia#2 Unit 4 983 May Alicia#2 Unit 5 983 May Alicia#2 Unit 6 983 MayCora Unit 1 983 MayCora Unit 2 983 MayCora Unit 3 983 MayCora Unit 4 983 MayCora Unit 5 983 MayCora Unit 6 983 May Federal

Unit 1 983 May Federal

Unit 2 983 May Federal

Unit 3 983 May Federal

Unit 4 983 May Federal

Unit 5 983 May Federal

Unit 6 983 May Rhino Unit 1 983 May Rhino Unit 2 983 May Rhino Unit 3

Page 60fuel_shipment_configurations

983 May Rhino Unit 4 983 May Rhino Unit 5 983 May Rhino Unit 6 983 NovAlicia#2

Unit 1 983 NovAlicia#2

Unit 2 983 NovAlicia#2

Unit 3 983 NovAlicia#2

Unit 4 983 NovAlicia#2

Unit 5 983 NovAlicia#2

Unit 6 983 NovCora Unit 1 983 NovCora Unit 2 983 NovCora Unit 3 983 NovCora Unit 4 983 NovCora Unit 5 983 NovCora Unit 6 983 NovFederal Unit 1 983 NovFederal Unit 2 983 NovFederal Unit 3 983 NovFederal Unit 4 983 NovFederal Unit 5 983 NovFederal Unit 6 983 NovRhino Unit 1 983 NovRhino Unit 2 983 NovRhino Unit 3 983 NovRhino Unit 4 983 NovRhino Unit 5 983 NovRhino Unit 6 983 OctAlicia#2 Unit 1 983 OctAlicia#2 Unit 2 983 OctAlicia#2 Unit 3 983 OctAlicia#2 Unit 4 983 OctAlicia#2 Unit 5 983 OctAlicia#2 Unit 6 983 OctCora Unit 1 983 OctCora Unit 2 983 OctCora Unit 3 983 OctCora Unit 4 983 OctCora Unit 5 983 OctCora Unit 6 983 OctFederal Unit 1 983 OctFederal Unit 2 983 OctFederal Unit 3 983 OctFederal Unit 4 983 OctFederal Unit 5 983 OctFederal Unit 6 983 OctRhino Unit 1 983 OctRhino Unit 2 983 OctRhino Unit 3 983 OctRhino Unit 4 983 OctRhino Unit 5 983 OctRhino Unit 6 983 SeptAlicia#2

Unit 1

Page 61fuel_shipment_configurations

983 SeptAlicia#2

Unit 2 983 SeptAlicia#2

Unit 3 983 SeptAlicia#2

Unit 4 983 SeptAlicia#2

Unit 5 983 SeptAlicia#2

Unit 6 983 SeptCora Unit 1 983 SeptCora Unit 2 983 SeptCora Unit 3 983 SeptCora Unit 4 983 SeptCora Unit 5 983 SeptCora Unit 6 983 SeptRhino Unit 1 983 SeptRhino Unit 2 983 SeptRhino Unit 3 983 SeptRhino Unit 4 983 SeptRhino Unit 5 983 SeptRhino Unit 6 2876 AprilCora Unit 1 2876 AprilCora Unit 2 2876 AprilCora Unit 3 2876 AprilCora Unit 4 2876 AprilCora Unit 5 2876 AprilEastern

Unit 1 2876 AprilEastern

Unit 2 2876 AprilEastern

Unit 3 2876 AprilEastern

Unit 4 2876 AprilEastern

Unit 5 2876 AugEasternUnit 1 2876 AugEasternUnit 2 2876 AugEasternUnit 3 2876 AugEasternUnit 4 2876 AugEasternUnit 5 2876 AugustCora

Unit 1 2876 AugustCora

Unit 2 2876 AugustCora

Unit 3 2876 AugustCora

Unit 4 2876 AugustCora

Unit 5 2876 DecEastern

Unit 1 2876 DecEastern

Unit 2 2876 DecEastern

Unit 3 2876 DecEastern

Unit 4 2876 DecEastern

Unit 5 2876 DecemberCora

Unit 1 2876 DecemberCora

Unit 2 2876 DecemberCora

Unit 3 2876 DecemberCora

Unit 4 2876 DecemberCora

Unit 5 2876 FebEastern Unit 1 2876 FebEastern Unit 2 2876 FebEastern Unit 3 2876 FebEastern Unit 4 2876 FebEastern Unit 5

Page 62fuel_shipment_configurations

2876 FebruaryCora

Unit 1 2876 FebruaryCora

Unit 2 2876 FebruaryCora

Unit 3 2876 FebruaryCora

Unit 4 2876 FebruaryCora

Unit 5 2876 JanEastern Unit 1 2876 JanEastern Unit 2 2876 JanEastern Unit 3 2876 JanEastern Unit 4 2876 JanEastern Unit 5 2876 JanuaryCora

Unit 1 2876 JanuaryCora

Unit 2 2876 JanuaryCora

Unit 3 2876 JanuaryCora

Unit 4 2876 JanuaryCora

Unit 5 2876 JulyCora Unit 1 2876 JulyCora Unit 2 2876 JulyCora Unit 3 2876 JulyCora Unit 4 2876 JulyCora Unit 5 2876 July EasternUnit 1 2876 July EasternUnit 2 2876 July EasternUnit 3 2876 July EasternUnit 4 2876 July EasternUnit 5 2876 JuneCora Unit 1 2876 JuneCora Unit 2 2876 JuneCora Unit 3 2876 JuneCora Unit 4 2876 JuneCora Unit 5 2876 JuneEastern

Unit 1 2876 JuneEastern

Unit 2 2876 JuneEastern

Unit 3 2876 JuneEastern

Unit 4 2876 JuneEastern

Unit 5 2876 MarchCora Unit 1 2876 MarchCora Unit 2 2876 MarchCora Unit 3 2876 MarchCora Unit 4 2876 MarchCora Unit 5 2876 MarchEastern

Unit 1 2876 MarchEastern

Unit 2 2876 MarchEastern

Unit 3 2876 MarchEastern

Unit 4 2876 MarchEastern

Unit 5 2876 MayCora Unit 1 2876 MayCora Unit 2 2876 MayCora Unit 3 2876 MayCora Unit 4 2876 MayCora Unit 5 2876 May Eastern

Unit 1 2876 May Eastern

Unit 2

Page 63fuel_shipment_configurations

2876 May Eastern

Unit 3 2876 May Eastern

Unit 4 2876 May Eastern

Unit 5 2876 NovEasternUnit 1 2876 NovEasternUnit 2 2876 NovEasternUnit 3 2876 NovEasternUnit 4 2876 NovEasternUnit 5 2876 Novem berCora

Unit 1 2876 Novem berCora

Unit 2 2876 Novem berCora

Unit 3 2876 Novem berCora

Unit 4 2876 Novem berCora

Unit 5 2876 OctEastern Unit 1 2876 OctEastern Unit 2 2876 OctEastern Unit 3 2876 OctEastern Unit 4 2876 OctEastern Unit 5 2876 OctoberCora

Unit 1 2876 OctoberCora

Unit 2 2876 OctoberCora

Unit 3 2876 OctoberCora

Unit 4 2876 OctoberCora

Unit 5 2876 SeptEastern

Unit 1 2876 SeptEastern

Unit 2 2876 SeptEastern

Unit 3 2876 SeptEastern

Unit 4 2876 SeptEastern

Unit 5 2876 Septem berCora

Unit 1 2876 Septem berCora

Unit 2 2876 Septem berCora

Unit 3 2876 Septem berCora

Unit 4 2876 Septem berCora

Unit 5

Page 64fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units

Page 65fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_type

supplier_name

supplier_address

Page 66fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies

Page 67fuel_shipment_samples

analysis_copies

Page 68fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL

Page 69test_reports

facility _id report_id report_type other_type report_description report_begin_date

report_end_date

before_control

during_deviation 983 Stack1Particulate2005

compliance Particulate Compliance Test 8/12/2005 8/12/2005 No No 983 Stack1Particulate2007

compliance Particulate Compliance Test 9/5/2007 9/5/2007 No No 983 Stack1Particulate2009

compliance Particulate Compliance Test 8/26/2009 8/26/2009 No No 983 Stack2Particulate2005

compliance Particulate Compliance Test 8/11/2005 8/11/2005 No No 983 Stack2Particulate2007

compliance Particulate Compliance Test 9/6/2007 9/6/2007 No No 983 Stack2Particulate2009

compliance Particulate Compliance Test 8/25/2009 8/25/2009 No No 2876 Unit1Particulate2005

compliance Particulate Compliance Test 8/16/2005 8/16/2005 No No 2876 Unit1Particulate2007

compliance Particulate Compliance Test 7/17/2007 7/17/2007 No No 2876 Unit2Particulate2005

compliance Particulate Compliance Test 8/23/2005 8/23/2005 No No 2876 Unit2Particulate2007

compliance Particulate Compliance Test 7/24/2007 7/24/2007 No No 2876 Unit3Particulate2005

compliance Particulate Compliance Test 8/17/2005 8/17/2005 No No 2876 Unit3Particulate2007

compliance Particulate Compliance Test 7/19/2007 7/19/2007 No No 2876 Unit4Particulate2005

compliance Particulate Compliance Test 8/25/2005 8/25/2005 No No 2876 Unit4Particulate2007

compliance Particulate Compliance Test 8/7/2007 8/7/2007 No No 2876 Unit5Particulate2005

compliance Particulate Compliance Test 8/18/2005 8/18/2005 No No 2876 Unit5Particulate2007

compliance Particulate Compliance Test 7/18/2007 7/18/2007 No No

Page 70test_reports

deviation_reports No No No No No No No No No No No No No No No No

Page 71test_report_configurations

facility _id report_id configuration_id 983 Stack1Particulate2005

Unit 1 983 Stack1Particulate2005

Unit 2 983 Stack1Particulate2005

Unit 3 983 Stack1Particulate2007

Unit 1 983 Stack1Particulate2007

Unit 2 983 Stack1Particulate2007

Unit 3 983 Stack1Particulate2009

Unit 1 983 Stack1Particulate2009

Unit 2 983 Stack1Particulate2009

Unit 3 983 Stack2Particulate2005

Unit 4 983 Stack2Particulate2005

Unit 5 983 Stack2Particulate2005

Unit 6 983 Stack2Particulate2007

Unit 4 983 Stack2Particulate2007

Unit 5 983 Stack2Particulate2007

Unit 6 983 Stack2Particulate2009

Unit 4 983 Stack2Particulate2009

Unit 5 983 Stack2Particulate2009

Unit 6 2876 Unit1Particulate2005

Unit 1 2876 Unit1Particulate2007

Unit 1 2876 Unit2Particulate2005

Unit 2 2876 Unit2Particulate2007

Unit 2 2876 Unit3Particulate2005

Unit 3 2876 Unit3Particulate2007

Unit 3 2876 Unit4Particulate2005

Unit 4 2876 Unit4Particulate2007

Unit 4 2876 Unit5Particulate2005

Unit 5 2876 Unit5Particulate2007

Unit 5

Page 72test_report_fuels

facility _id report_id fuel_id 983 Stack1Particulate2005

Representative Blend 983 Stack1Particulate2007

Representative Blend 983 Stack1Particulate2009

Representative Blend 983 Stack2Particulate2005

Representative Blend 983 Stack2Particulate2007

Representative Blend 983 Stack2Particulate2009

Representative Blend 2876 Unit1Particulate2005

Representative Blend 2876 Unit1Particulate2007

Representative Blend 2876 Unit2Particulate2005

Representative Blend 2876 Unit2Particulate2007

Representative Blend 2876 Unit3Particulate2005

Representative Blend 2876 Unit3Particulate2007

Representative Blend 2876 Unit4Particulate2005

Representative Blend 2876 Unit4Particulate2007

Representative Blend 2876 Unit5Particulate2005

Representative Blend 2876 Unit5Particulate2007

Representative Blend

Page 73test_report_fuel_types

facility _id report_id fuel_id fuel_type percentage_massvol percentage_btu

other_type 983 Stack1Particulate2005

Representative Blend

coal - bituminous 41 983 Stack1Particulate2005

Representative Blend

coal - subbituminous

59 983 Stack1Particulate2007

Representative Blend

coal - bituminous 32 983 Stack1Particulate2007

Representative Blend

coal - subbituminous

68 983 Stack1Particulate2009

Representative Blend

coal - bituminous 25 983 Stack1Particulate2009

Representative Blend

coal - subbituminous

75 983 Stack2Particulate2005

Representative Blend

coal - bituminous 41 983 Stack2Particulate2005

Representative Blend

coal - subbituminous

59 983 Stack2Particulate2007

Representative Blend

coal - bituminous 31 983 Stack2Particulate2007

Representative Blend

coal - subbituminous

69 983 Stack2Particulate2009

Representative Blend

coal - bituminous 28 983 Stack2Particulate2009

Representative Blend

coal - subbituminous

72 2876 Unit1Particulate2005

Representative Blend

coal - bituminous 71 2876 Unit1Particulate2005

Representative Blend

coal - subbituminous

29 2876 Unit1Particulate2007

Representative Blend

coal - bituminous 35 2876 Unit1Particulate2007

Representative Blend

coal - subbituminous

65 2876 Unit2Particulate2005

Representative Blend

coal - bituminous 91 2876 Unit2Particulate2005

Representative Blend

coal - subbituminous 9 2876 Unit2Particulate2007

Representative Blend

coal - bituminous 45 2876 Unit2Particulate2007

Representative Blend

coal - subbituminous

55 2876 Unit3Particulate2005

Representative Blend

coal - bituminous 82 2876 Unit3Particulate2005

Representative Blend

coal - subbituminous

18 2876 Unit3Particulate2007

Representative Blend

coal - bituminous 46 2876 Unit3Particulate2007

Representative Blend

coal - subbituminous

54 2876 Unit4Particulate2005

Representative Blend

coal - bituminous 69 2876 Unit4Particulate2005

Representative Blend

coal - subbituminous

31 2876 Unit4Particulate2007

Representative Blend

coal - bituminous 35 2876 Unit4Particulate2007

Representative Blend

coal - subbituminous

65 2876 Unit5Particulate2005

Representative Blend

coal - bituminous 51 2876 Unit5Particulate2005

Representative Blend

coal - subbituminous

49 2876 Unit5Particulate2007

Representative Blend

coal - bituminous 38 2876 Unit5Particulate2007

Representative Blend

coal - subbituminous

62

Page 74cem_data

facility _id tim e_period

cem_period_description

Page 75cem_data_pollutants1

facility _id tim e_period

pollutant_nam e

Page 76test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_bypass_percent

testing_bypass_percent 983 Stack1Particulate2005

COMMON STACK 1

No No 983 Stack1Particulate2007

COMMON STACK 1

No No 983 Stack1Particulate2009

COMMON STACK 1

No No 983 Stack2Particulate2005

COMMON STACK 2

No No 983 Stack2Particulate2007

COMMON STACK 2

No No 983 Stack2Particulate2009

COMMON STACK 2

No No 2876 Unit1Particulate2005

UNIT 1 DUCT

No No 2876 Unit1Particulate2007

UNIT 1 DUCT

No No 2876 Unit2Particulate2005

UNIT 2 DUCT

No No 2876 Unit2Particulate2007

UNIT 2 DUCT

No No 2876 Unit3Particulate2005

UNIT 3 DUCT

No No 2876 Unit3Particulate2007

UNIT 3 DUCT

No No 2876 Unit4Particulate2005

UNIT 4 DUCT

No No 2876 Unit4Particulate2007

UNIT 4 DUCT

No No 2876 Unit5Particulate2005

UNIT 5 DUCT

No No 2876 Unit5Particulate2007

UNIT 5 DUCT

No No

Page 77test_report_sampling

fg_fraction

Page 78sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 983 Stack1Particulate2005

COMMON STACK 1

average 8/12/2005 8/12/2005 666 10.1 983 Stack1Particulate2007

COMMON STACK 1

average 9/5/2007 9/5/2007 634 9.7 983 Stack1Particulate2009

COMMON STACK 1

average 8/26/2009 8/26/2009 614 10.5 983 Stack2Particulate2005

COMMON STACK 2

average 8/11/2005 8/11/2005 648 10.2 983 Stack2Particulate2007

COMMON STACK 2

average 9/6/2007 9/6/2007 633 10.7 983 Stack2Particulate2009

COMMON STACK 2

average 8/25/2009 8/25/2009 606 9.9 2876 Unit1Particulate2005

UNIT 1 DUCT

average 8/16/2005 8/16/2005 206 9.7 2876 Unit1Particulate2007

UNIT 1 DUCT

average 7/17/2007 7/17/2007 212 9.4 2876 Unit2Particulate2005

UNIT 2 DUCT

average 8/23/2005 8/23/2005 212 7.3 2876 Unit2Particulate2007

UNIT 2 DUCT

average 7/24/2007 7/24/2007 186 10.4 2876 Unit3Particulate2005

UNIT 3 DUCT

average 8/17/2005 8/17/2005 213 9.6 2876 Unit3Particulate2007

UNIT 3 DUCT

average 7/19/2007 7/19/2007 210 10.9 2876 Unit4Particulate2005

UNIT 4 DUCT

average 8/25/2005 8/25/2005 203 8.3 2876 Unit4Particulate2007

UNIT 4 DUCT

average 8/7/2007 8/7/2007 215 9.6 2876 Unit5Particulate2005

UNIT 5 DUCT

average 8/18/2005 8/18/2005 210 10.1 2876 Unit5Particulate2007

UNIT 5 DUCT

average 7/18/2007 7/18/2007 211 10

Page 79sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 1616450 dscfm 7 13 1580566 dscfm 7.3 12.4 1521039 dscfm 9.1 10.8 1622603 dscfm 7.2 12.9 1571426 dscfm 7.4 12.3 1540455 dscfm 8.9 10.6 531352 dscfm 8.1 12.3 498739 dscfm 6.6 12.3 534243 dscfm 8.1 11.4 490411 dscfm 5.9 12.7 548552 dscfm 7 12 508882 dscfm 6.8 12.1 571528 dscfm 8 11.3 517738 dscfm 5.9 12.7 491817 dscfm 7 12 539856 dscfm 6.8 12.2

Page 80sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value Methods 1-5 Representative Blend 8.64 12740 Methods 1-5,202 Representative Blend 8.26 12974 Methods 1-5,202 Representative Blend 7.43 12591 Methods 1-5 Representative Blend 6.74 13030 Methods 1-5,202 Representative Blend 8.79 12739 Methods 1-5,202 Representative Blend 7.35 12642 Methods 1-5 Representative Blend 10.56 13026 Methods 1-5,202 Representative Blend 10.08 12571 Methods 1-5 Representative Blend 11.08 12961 Methods 1-5,202 Representative Blend 9.27 12716 Methods 1-5 Representative Blend 10.28 13040 Methods 1-5,202 Representative Blend 9.44 12665 Methods 1-5 Representative Blend 10.01 13303 Methods 1-5,202 Representative Blend 8.38 12777 Methods 1-5 Representative Blend 10.08 13087 Methods 1-5,202 Representative Blend 9.16 12784

Page 81sampling_runs

fuel_sulfur 1.85 1.35 0.71 1.1 1.17 0.58 0.65 1.23 1.08 0.74 0.67 1.23 0.95 1.06 0.73 1.37

Page 82sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 2876 Unit1Particulate2005

UNIT 1 DUCT

average PM (Filterable) FALSE 2876 Unit2Particulate2005

UNIT 2 DUCT

average PM (Filterable) FALSE 2876 Unit3Particulate2005

UNIT 3 DUCT

average PM (Filterable) FALSE 2876 Unit4Particulate2005

UNIT 4 DUCT

average PM (Filterable) FALSE 2876 Unit5Particulate2005

UNIT 5 DUCT

average PM (Filterable) FALSE 2876 Unit1Particulate2007

UNIT 1 DUCT

average PM (Filterable) 47.713 mi lligram per cubic meter (mg/m3) FALSE 2876 Unit2Particulate2007

UNIT 2 DUCT

average PM (Filterable) FALSE 2876 Unit3Particulate2007

UNIT 3 DUCT

average PM (Filterable) 32.046 mi lligram per cubic meter (mg/m3) FALSE 2876 Unit5Particulate2007

UNIT 5 DUCT

average PM (Filterable) 37.948 mi lligram per cubic meter (mg/m3) FALSE 2876 Unit4Particulate2007

UNIT 4 DUCT

average PM (Filterable) FALSE 2876 Unit1Particulate2007

UNIT 1 DUCT

average PM (Condensable) 144.122 mi lligram per cubic meter (mg/m3)

FALSE 2876 Unit2Particulate2007

UNIT 2 DUCT

average PM (Condensable) 99.272 mi lligram per cubic meter (mg/m3)

FALSE 2876 Unit3Particulate2007

UNIT 3 DUCT

average PM (Condensable) 112.061 mi lligram per cubic meter (mg/m3)

FALSE 2876 Unit4Particulate2007

UNIT 4 DUCT

average PM (Condensable) 114.122 mi lligram per cubic meter (mg/m3)

FALSE 2876 Unit5Particulate2007

UNIT 5 DUCT

average PM (Condensable) 114.658 mi lligram per cubic meter (mg/m3)

FALSE 983 Stack1Particulate2005

COMMON STACK 1

average PM (Filterable) FALSE 983 Stack1Particulate2007

COMMON STACK 1

average PM (Filterable) FALSE 983 Stack1Particulate2007

COMMON STACK 1

average PM (Condensable) FALSE 983 Stack1Particulate2009

COMMON STACK 1

average PM (Filterable) 11.984 mi lligram per cubic meter (mg/m3) FALSE 983 Stack1Particulate2009

COMMON STACK 1

average PM (Condensable) FALSE 983 Stack2Particulate2005

COMMON STACK 2

average PM (Filterable) FALSE 983 Stack2Particulate2007

COMMON STACK 2

average PM (Filterable) FALSE 983 Stack2Particulate2007

COMMON STACK 2

average PM (Condensable) FALSE 983 Stack2Particulate2009

COMMON STACK 2

average PM (Filterable) 45.539 mi lligram per cubic meter (mg/m3) FALSE 983 Stack2Particulate2009

COMMON STACK 2

average PM (Condensable) FALSE

Page 83sampling_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 104.937 pound per hour (lb/hr)

FALSE 0.0528 pound per million British Thermal Unit (lb/MMBtu) FALSE 64.338 pound per hour (lb/hr)

FALSE 0.032 pound per million British Thermal Unit (lb/MMBtu) FALSE 99.9 pound per hour (lb/hr)

FALSE 0.0447 pound per million British Thermal Unit (lb/MMBtu) FALSE 25.783 pound per hour (lb/hr)

FALSE 0.0119 pound per million British Thermal Unit (lb/MMBtu) FALSE 109.673 pound per hour (lb/hr)

FALSE 0.0547 pound per million British Thermal Unit (lb/MMBtu) FALSE 96.545 pound per hour (lb/hr)

FALSE 0.0463 pound per million British Thermal Unit (lb/MMBtu) FALSE 56.492 pound per hour (lb/hr)

FALSE 0.0261 pound per million British Thermal Unit (lb/MMBtu) FALSE 65.372 pound per hour (lb/hr)

FALSE 0.0313 pound per million British Thermal Unit (lb/MMBtu) FALSE 80.636 pound per hour (lb/hr)

FALSE 0.0361 pound per million British Thermal Unit (lb/MMBtu) FALSE 46.232 pound per hour (lb/hr)

FALSE 0.0202 pound per million British Thermal Unit (lb/MMBtu) FALSE 290.934 pound per hour (lb/hr)

FALSE 0.1392 pound per million British Thermal Unit (lb/MMBtu) FALSE 194.942 pound per hour (lb/hr)

FALSE 0.0905 pound per million British Thermal Unit (lb/MMBtu) FALSE 229.201 pound per hour (lb/hr)

FALSE 0.109 pound per million British Thermal Unit (lb/MMBtu) FALSE 230.655 pound per hour (lb/hr)

FALSE 0.1011 pound per million British Thermal Unit (lb/MMBtu) FALSE 242.922 pound per hour (lb/hr)

FALSE 0.1094 pound per million British Thermal Unit (lb/MMBtu) FALSE 81.742 pound per hour (lb/hr)

FALSE 0.0124 pound per million British Thermal Unit (lb/MMBtu) FALSE 38.278 pound per hour (lb/hr)

FALSE 0.0061 pound per million British Thermal Unit (lb/MMBtu) FALSE 36.404 pound per hour (lb/hr)

FALSE 0.0058 pound per million British Thermal Unit (lb/MMBtu) FALSE 68.264 pound per hour (lb/hr)

FALSE 0.013 pound per million British Thermal Unit (lb/MMBtu) FALSE 81.65 pound per hour (lb/hr)

FALSE 0.0156 pound per million British Thermal Unit (lb/MMBtu) FALSE 304.97 pound per hour (lb/hr)

FALSE 0.0468 pound per million British Thermal Unit (lb/MMBtu) FALSE 194.54 pound per hour (lb/hr)

FALSE 0.0312 pound per million British Thermal Unit (lb/MMBtu) FALSE 48.599 pound per hour (lb/hr)

FALSE 0.0078 pound per million British Thermal Unit (lb/MMBtu) FALSE 261.531 pound per hour (lb/hr)

FALSE 0.0485 pound per million British Thermal Unit (lb/MMBtu) FALSE 112.84 pound per hour (lb/hr)

FALSE 0.0206 pound per million British Thermal Unit (lb/MMBtu) FALSE

Page 84sampling_run_pollutants1

run_pollutant_comment

Page 85sampling_run_fuel

facility _id report_id sampling_port_id run_id fuel_pollutant fuel_conc fuel_conc_units fuel_conc_ND

fuel_conc_MDL

Page 86sampling_run_fuel

fuel_conc_MDL

Page 87