Facility _Information facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_ty pe

legal_address

legal_city legal_state legal_zip 6761 15143 Platte River Power Authority Platte River Power Authority

legal owner2000 East Horsetooth Road Fort Collins CO 80525-5721

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 Rawhide Rawhide Energy Station2700 East County Road 82 We llington CO 80549-2105 2000 East Horsetooth Road

Fort Collins CO 80525-5721

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 FALSE TRUE TRUE FALSE

Page 3Facility _Information ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note FALSE FALSE Title V Operating Permit Yes Colorado Department of Public Health and Environment Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 4Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 5Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 6Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 7Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 8Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 9Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 10Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 11Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 12Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 13Facility _Information Part I Notes:Note: The" Design Steam Pressure" and "Operating Steam Pressure" are the turbine throttle design and operating pressures which are what is typically reported. 1. Design Steam Temperature (F) = 10051. Operating Steam Temperature (F) = 10051. Design Steam Reheat Temperature (F) = 10051. Operating Steam Reheat Temperature (F) = 1005The Estimated Retirement Year is the EIA-860 date. There are no actual plans to retire the plant within the foreseeable future. The "Advanced Overfire Air" entry under the Boiler Information - Nitrogen Oxide Control tab is actually Separated Overfire Air, which was not a available selection.  The reported Mercury Control Project is NOT a Demonstration Project. The Demonstration Project information filled-in automatically when the Non-Demonstration tab entry was completed.The Combustion Engineering (CE) boiler manufacturer contract guaranteed the following:The original Performance Guarantee on the Steam Generator for NOx Emissions lea

Page 14facility _contacts facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 6761 1 Senior Environm ental Analyst Paul Schulz

9702291762

9702184541

schulzp@prpa.org

TRUE 6761 2 Engineering Services Manager Rocky Knutson 9702291756

9702176634

knutsonr@prpa.org

FALSE

Page 15facility _coal_utilized facility _id coal_ty pe percentage_mass percentage_btu

sy nfuel_ty pe

coal_note 6761 subbituminous 100 100 Rawhide is a base-loaded coal-fired plant burning PRB subbitumious coal. Rawhide burns a 80/20 bio-diesel blend as startup fuel. In 2009, coal represented 99.99% of the total unit heat input.

Page 16facility _coal_utilized Rawhide is a base-loaded coal-fired plant burning PRB subbitumious coal. Rawhide burns a 80/20 bio-diesel blend as startup fuel. In 2009, coal represented 99.99% of the total unit heat input.

Page 17facility _coal_utilized Rawhide is a base-loaded coal-fired plant burning PRB subbitumious coal. Rawhide burns a 80/20 bio-diesel blend as startup fuel. In 2009, coal represented 99.99% of the total unit heat input.

Page 18facility _oil_utilized facility _id oil_ty pe percentage_volume percentage_btu

other_ty pe 6761 other (specify) 100 100 Blue Sun Bio-Diesel 80/20

Page 19facility _other_materials facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain

Page 20facility _other_materials rcra_explain

Page 21boiler_information

facility _id boiler_id boiler_ty pe boiler_other bottom_design

design_fuel heat_input ma x_heat_input MW e_capacity 6761 101 Tangential firing Dry Bottom coal 2800 2800 305

Page 22boiler_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 278 85.6 83.5 1890 1890 1 1 FALSE 1

Page 23boiler_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 1 8320.3 91.1 Subpart Da(1) 2034 FALSE

Page 24boiler_information

NOx_control

SO2_control

combustion_additives Yes Yes No

Page 25boiler_fuels

facility _id boiler_id fuel_ty pe fuel_year percentage_massvol percentage_btu

other_ty pe 6761 101 coal - subbituminous 2007 99.95 99.95 6761 101 coal - subbituminous 2008 99.91 99.91 6761 101 coal - subbituminous 2009 99.99 99.99 6761 101 oil - other 2007 0.05 0.05 Blue Sun Bio-Diesel, 80/20 Blend 6761 101 oil - other 2008 0.09 0.09 Blue Sun Bio-Diesel, 80/20 Blend 6761 101 oil - other 2009 0.01 0.01 Blue Sun Bio-Diesel, 80/20 Blend

Page 26boiler_control_NOx

facility _id boiler_id NOx_ty pe NOx_other NOx_online 6761 101 Advanced Overfire Air 11/1/2005 6761 101 Low NOx Burner 4/1/1984 6761 101 Other (specify) Level III Low-NOx Burners

11/1/2005 6761 101 Overfire Air 4/1/1984

Page 27boiler_control_SO2

facility _id boiler_id SO2_ty pe SO2_other SO2_online 6761 101 Low Sulfur Coal 4/1/1984 6761 101 Low Sulfur Fuel Oil 1/1/1995

Page 28boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online

Page 29facility _units facility _id unit_id 6761 101

Page 30unit_boilers

facility _id unit_id boiler_id 6761 101 101

Page 31facility _controls facility _id control_id control_group control_ty pe

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 6761 FF PM control Fabric Filter, reverse air FALSE 4/1/1984 6761 SDA SO2 control Spray dryer ty pe FALSE 4/1/1984

Page 32facility _controls reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive Lim e and alkaline fly

ash no

Page 33facility _sampling_ports facility _id sampling_port_id 6761 SDA Inlet 6761 Stack

Page 34facility _stacks facility _id stack_id stack_height stack_diameter

sack_gas_velocity 6761 S101 505 18.5 60

Page 35configurations

facility _id configuration_id 6761 Rawhide101

Page 36configuration_components

facility _id configuration_id

component_id

order component_ty pe port_near 6761 Rawhide101

101 1 Unit 6761 Rawhide101

FF 4 PM control 6761 Rawhide101

S101 6 Stack 6761 Rawhide101

SDA 3 SO2 control 6761 Rawhide101

SDA Inlet 2 Sam pling Port pevious 6761 Rawhide101

Stack 5 Sam pling Port next

Page 37configuration_pollutants1

facility _id configuration_id

pollutant_nam e

permit_ty pe_1

em lim it_1 em lim it_units_1 avg_period_1

em lim it_2 em lim it_units_2 6761 Rawhide101

PM (Filterable)

State - State Operating Permit

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

1 hour 6761 Rawhide101

Sulfur Dioxide (SO2)

State - State Operating Permit

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

3 hours 0.13 pound per million British Thermal Unit (lb/MMBtu) 6761 Rawhide101

Nitrogen Oxide (NOx)

State - State Operating Permit

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

30 days 0.18 pound per million British Thermal Unit (lb/MMBtu) 6761 Rawhide101

Carbon Monoxide (CO)

State - Permit to Contruct

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

8 hours 0.4 pound per million British Thermal Unit (lb/MMBtu)

Page 38configuration_pollutants1

avg_period_2

em lim it_details

test_method

em rate em rate_units guarantee_level

_explain

req_monitoring

eq_recordkeeping 80 pound per hour (lb/hr)

Yes The particulate content of the flue gas stream at the outlet of the system shall not exceed 23 lbs/hour at 25% load, 55 lbs/hour at 75% load, 72 lbs/hour at rated load, and 80 lbs/hour at MCR. The permitted emission rate is 0.03 lbs/mmBtu. COM (opacity) and annual Method 5 PM Testing, per operating permit.

Per Title V Permit General Conditin 22.: Record Keeping and Reporting RequirementsRegulation No. 3, 5 CCR 1001-5, Part A, § II.; Part C, §§ V.C.6., V.C.7.a.Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain compliance monitoring records that include the following information:(i)date, place as defined in the Operating Permit, and time of sampling or measurements;(ii)date(s) on which analy ses were performed;(iii)the company or entity that performed the analysis;(iv)the analy tical techniques or methods used;(v)the results of such analysis; and(vi)the operating conditions at the time of sampling or measurement.b.The permittee shall retain records of all required monitoring data and support information for a period of at least five (5) years from the date of the monitoring sample, measurement, report or application. Support information, for this purpose, includes all calibration and maintenance records and all original str 30 days Must also meet 80% SO2 Removal over 30-day rolling average, and meet State-only lim it of 0.09 lbs/mmBtu (calendar year average). 0.13 pound per million British Thermal Unit (lb/MMBtu)

No The Joy-Niro (scrubber and baghouse manufacturer) contract had the following statement/guarentee: The sulfur dioxide removal efficiency shall equal or exceed 80% removal and 0.13 lbs./mmBtu. The 0.09 lbs/mmBtu is state-only Lim it, not guarantee. CEMS, both at stack and inlet to SO2 scrubber, per operating permit.

Per Title V Permit General Conditin 22.: Record Keeping and Reporting RequirementsRegulation No. 3, 5 CCR 1001-5, Part A, § II.; Part C, §§ V.C.6., V.C.7.a.Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain compliance monitoring records that include the following information:(i)date, place as defined in the Operating Permit, and time of sampling or measurements;(ii)date(s) on which analy ses were performed;(iii)the company or entity that performed the analysis;(iv)the analy tical techniques or methods used;(v)the results of such analysis; and(vi)the operating conditions at the time of sampling or measurement.b.The permittee shall retain records of all required monitoring data and support information for a period of at least five (5) years from the date of the monitoring sample, measurement, report or application. Support information, for this purpose, includes all calibration and maintenance records and all original str 30 days The 0.18 lbs/mmBtu limit is a State-only calendar year average limit. 0.17 pound per million British Thermal Unit (lb/MMBtu)

Yes The origional Performance Guarantee on the Steam Generator for NOx Emissions leaving the air heater was 0.50 lbs./mmBtu. The origional guarantee was superseeded with the LNCFS Level III burner and SOFA project's 0.17 lbs/mmBtu NOx guarantee. CEMS per operating permit requirements.

Per Title V Permit General Conditin 22.: Record Keeping and Reporting RequirementsRegulation No. 3, 5 CCR 1001-5, Part A, § II.; Part C, §§ V.C.6., V.C.7.a.Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain compliance monitoring records that include the following information:(i)date, place as defined in the Operating Permit, and time of sampling or measurements;(ii)date(s) on which analy ses were performed;(iii)the company or entity that performed the analysis;(iv)the analy tical techniques or methods used;(v)the results of such analysis; and(vi)the operating conditions at the time of sampling or measurement.b.The permittee shall retain records of all required monitoring data and support information for a period of at least five (5) years from the date of the monitoring sample, measurement, report or application. Support information, for this purpose, includes all calibration and maintenance records and all original str 8 hours The 0.40 lbs/mmBtu limit is a startup/shutdown duration limit which converts to an 8-hour rolling averaging period for startup lasting more thatn 8 hours. Limits will be incorporated into Operating Permit during next renewal. 0.15 pound per million British Thermal Unit (lb/MMBtu)

No The 0.15 lbs/mmBtu is the emissions limit. 100 ppm is the actual guaranteee, but was not entered since ppm units was not included as a selectable Meas. Units. CEMS, per state construction permit.

Per State Construction Permit specified requirements

Page 39configuration_pollutants1

req_reporting Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per State Construction Permit specified requirements.

Page 40configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 41configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 42configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 43configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 44configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 45configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 46configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 47configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 48configuration_pollutants1 Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set Per Title V Permit and Part 70 Operating Permit program requires three ty pes of reports to be filed;. All required reports must be certified by a responsible official.Report #1: Monitoring Deviation Report (due at least every six months)For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by

data from any

monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring.Report #2: Permit Deviation Report (must be reported “promptly”)In addition to the monitoring requirements set

Page 49control_technologies

facility _id configuration_id

component_id

control_id project_title project_ty pe vendor_name

vndor_contact

vendor_phone 6761 Rawhide101

101 101 Mercury Control System Demonstration

Norit Americas Inc.

Richard McKnight

9039354796

Page 50control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive 3200 University

Avenue Marshall TX 75671 7/1/2010 Brominated PAC Bromine

Page 51control_technologies

injection_point

HAP_em ission_reduction

HAP_em ission_rate

HAP_em ission_rate_units

HAP_achieved_reduction

HAP_achieved_rate

HAP_achieved_rate_units

feed_rate feed_rate_units Air Heater Outlet/ SDA Inlet Duct

90 8.7E-06 lb/MW h

Page 52control_technologies feed_rate_units

Page 53control_coal_ranks

facility _id configuration_id

component_id

control_id coal_ty pe 6761 Rawhide101

101 101 subbituminous

Page 54control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e 6761 Rawhide101

101 101 Total Mercury (Hgt)

Page 55control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year 6761 Rawhide101

101 101 Yes No 3190000 2100000 2009

Page 56control_costs

CBI FALSE

Page 57mi sc_controls

facility _id mi sc_control_id

control_description

Page 58mi sc_control_configurations

facility _id mi sc_control_id

configuration_id

Page 59fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_ty pe state_country other_country

county 6761 April 2009 4/1/2009 117272.6 short tons (2000 lbs) coal WY WY - Converse 6761 August 2009 8/1/2009 109818.4 short tons (2000 lbs) coal WY WY - Converse 6761 December 2009

12/1/2009 109088 short tons (2000 lbs) coal WY WY - Converse 6761 February

2009 2/1/2009 108284.3 short tons (2000 lbs) coal WY WY - Converse 6761 January

20091/1/2009 116581.7 short tons (2000 lbs) coal WY WY - Converse 6761 July

2009 7/1/2009 109319.1 short tons (2000 lbs) coal WY WY - Converse 6761 June 2009 6/1/2009 104876.6 short tons (2000 lbs) coal WY WY - Converse 6761 March 2009 3/1/2009 108007.3 short tons (2000 lbs) coal WY WY - Converse 6761 May

2009 5/1/2009 117098.8 short tons (2000 lbs) coal WY WY - Converse 6761 Novem ber 2009

11/1/2009 109909.6 short tons (2000 lbs) coal WY WY - Converse 6761 October 2009

10/1/2009 109657.9 short tons (2000 lbs) coal WY WY - Converse 6761 Septem ber 2009

8/1/2009 112963.3 short tons (2000 lbs) coal WY WY - Converse

Page 60fuel_shipments

coal_seam shipment_method Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyor

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train Anderson and Canyon

Unit Train

Page 61fuel_shipment_configurations

facility _id shipment_id

configuration_id 6761 April 2009 Rawhide101 6761 August 2009

Rawhide101 6761 December 2009

Rawhide101 6761 February

2009 Rawhide101 6761 January

2009 Rawhide101 6761 July

2009 Rawhide101 6761 June 2009 Rawhide101 6761 March 2009

Rawhide101 6761 May

2009 Rawhide101 6761 Novem ber 2009

Rawhide101 6761 October 2009

Rawhide101 6761 Septem ber 2009

Rawhide101

Page 62fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units 6761 April 2009 41310 5182 tons 0.33 6.9 11973 Btu/lb 6761 April 2009 41369 4619 tons 0.33 7.23 11991 Btu/lb 6761 August 2009

41939 2651 tons 0.39 6.44 11942 Btu/lb 6761 August 2009

41995 459 tons 0.39 7.38 11928 Btu/lb 6761 December 2009

42592 4351 tons 0.29 5.83 12185 Btu/lb 6761 December 2009

42641 2364 tons 0.035 6.98 11979 Btu/lb 6761 December 2009

QTR4 8350 tons 0.38 6.99 11967 Btu/lb 6761 February

2009 40933 2855 tons 0.38 10.18 11503 Btu/lb 6761 February

2009 40989 6092 tons 0.36 7.07 11998 Btu/lb 6761 February

2009 41057 2379 tons 0.36 7.32 11988 Btu/lb 6761 January

2009 40771 4578 tons 0.29 7.32 11824 Btu/lb 6761 January

2009 40821 2710 tons 0.3 8.15 11692 Btu/lb 6761 January

2009 40878 2700 tons 0.38 7.16 11885 Btu/lb 6761 July

2009 41774 905 tons 0.33 6.88 11909 Btu/lb 6761 July

2009 41829 2226 tons 0.26 7.37 11793 Btu/lb 6761 July

2009 41886 870 tons 0.36 6.44 12061 Btu/lb 6761 June 2009 41607 1648 tons 0.33 6.42 12081 Btu/lb 6761 June 2009 41659 1456 tons 0.38 11.75 11351 Btu/lb 6761 June 2009 41719 981 tons 0.32 7.48 11964 Btu/lb 6761 June 2009 QTR2 8350 tons 0.29 6.41 12049 Btu/lb 6761 March 2009

41177 8369 tons 0.35 7.74 11771 Btu/lb 6761 March 2009

41245 752 tons 0.35 7.31 11867 Btu/lb 6761 March 2009

QTR1 8350 tons 0.28 8.38 11795 Btu/lb 6761 May

2009 41420 4208 tons 0.39 6.91 11986 Btu/lb 6761 May

2009 41488 2453 tons 0.37 6.86 11982 Btu/lb 6761 May

2009 41551 1678 tons 0.28 7.93 11788 Btu/lb 6761 May

2009 QTR1 8350 tons 0.28 8.38 11795 Btu/lb 6761 Novem ber 2009

42415 6626 tons 0.29 5.65 12081 Btu/lb 6761 Novem ber 2009

42465 3235 tons 0.35 8.07 11805 Btu/lb 6761 Novem ber 2009

42538 3334 tons 0.37 8.95 11740 Btu/lb 6761 October 2009

42238 2192 tons 0.37 7.5 11872 Btu/lb 6761 October 2009

42309 3615 tons 0.45 6.69 11970 Btu/lb 6761 October 2009

42369 2124 tons 0.36 9.11 11618 Btu/lb 6761 Septem ber 2009

42055 4414 tons 0.38 5.86 12095 Btu/lb 6761 Septem ber 2009

42110 4270 tons 0.36 7.46 11925 Btu/lb 6761 Septem ber 2009

42163 5566 tons 0.37 8.52 11605 Btu/lb 6761 Septem ber 2009

QRT3 8350 tons 0.38 8.68 11679 Btu/lb

Page 63fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_ty pe

supplier_name

supplier_address standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 11 parts per million (dry) (ppm) 55 parts per million (dry) (ppm)

permit requirements Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 10 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 10 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 11 parts per million (dry) (ppm) 70 parts per million (dry) (ppm)

permit requirements Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 62 parts per million (dry) (ppm)

permit requirements Other SGS North America Inc. 4665 Paris StreetSuite B-200 14 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 62 parts per million (dry) (ppm)

permit requirements Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 13 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 16 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 18 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 11 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 21 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 11 parts per million (dry) (ppm) standard operational procedures Other SGS North America Inc. 4665 Paris StreetSuite B-200 15 parts per million (dry) (ppm) 62 parts per million (dry) (ppm)

permit requirements Other SGS North America Inc. 4665 Paris StreetSuite B-200

Page 64fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 Yes Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 Yes Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 Yes Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 Yes Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 No Denver CO 80239 SGS North America Inc. 4665 Paris StreetSuite B-200

Denver CO 80239 Yes

Page 65fuel_shipment_samples analysis_copies

Page 66fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL 6761 April 2009 41310 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 April 2009 41310 Mercury (Hg) 7 parts per million (dry) (ppm) FALSE 6761 April 2009 41369 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 April 2009 41369 Mercury (Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 August 2009

41939 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 August 2009

41939 Mercury

(Hg) 0.07 parts per million (dry) (ppm) FALSE 6761 August 2009

41995 Chloride (Cl) 10 parts per million (dry) (ppm) FALSE 6761 August 2009

41995 Mercury

(Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 December 2009

42592 Chloride (Cl) 15 parts per million (dry) (ppm) FALSE 6761 December 2009

42592 Mercury

(Hg) 0.04 parts per million (dry) (ppm) FALSE 6761 December 2009

42641 Chloride (Cl) 12 parts per million (dry) (ppm) FALSE 6761 December 2009

42641 Mercury

(Hg) 0.04 parts per million (dry) (ppm) FALSE 6761 December 2009

QTR4 Antim ony

(Sb) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 December 2009

QTR4 Arsenic (As) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 December 2009

QTR4 Barium (Ba) 423 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Bery llium (Be) 0.2 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Cadmium (Cd) 0 mi crogram per gram (dry) (mg/g) TRUE 0.2 6761 December 2009

QTR4 Chloride (Cl) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Chromium (Cr) 5 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Cobalt (Co) 2 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Copper (Cu) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Fluoride (F) 55 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Lead (Pb) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 December 2009

QTR4 Manganese (Mn) 15 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Moly bdenum (Mo) 2 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Nickel (Ni) 4 mi crogram per gram (dry) (mg/g) FALSE 6761 December 2009

QTR4 Selenium (Se) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 December 2009

QTR4 Vanadium (V) 10 mi crogram per gram (dry) (mg/g) FALSE 6761 February

2009 40933 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 February

2009 40933 Mercury

(Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 February

2009 40989 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 February

2009 40989 Mercury

(Hg) 0.09 parts per million (dry) (ppm) FALSE 6761 February

2009 41057 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 February

2009 41057 Mercury

(Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 January

2009 40771 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 January

2009 40771 Mercury

(Hg) 0.07 parts per million (dry) (ppm) FALSE 6761 January

2009 40821 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 January

2009 40821 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 January

2009 40878 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 January

2009 40878 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 July

2009 41774 Chloride (Cl) 16 parts per million (dry) (ppm) FALSE 6761 July

2009 41774 Mercury (Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 July

2009 41829 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 July

2009 41829 Mercury (Hg) 0.07 parts per million (dry) (ppm) FALSE 6761 July

2009 41886 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 July

2009 41886 Mercury (Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 June 2009 41607 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 June 2009 41607 Mercury (Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 June 2009 41659 Chloride (Cl) 10 parts per million (dry) (ppm) FALSE 6761 June 2009 41659 Mercury (Hg) 0.16 parts per million (dry) (ppm) FALSE 6761 June 2009 41719 Chloride (Cl) 10 parts per million (dry) (ppm) FALSE Page 67fuel_sample_pollutants

6761 June 2009 41719 Mercury (Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 June 2009 QTR2 Antim ony (Sb) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 June 2009 QTR2 Arsenic (As) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 June 2009 QTR2 Barium (Ba) 367 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Bery llium (Be) 0.2 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Cadmium (Cd) 0 mi crogram per gram (dry) (mg/g) TRUE 0.2 6761 June 2009 QTR2 Chloride (Cl) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Chromium (Cr) 4 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Cobalt (Co) 3 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Copper (Cu) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Fluoride (F) 70 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Lead (Pb) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 June 2009 QTR2 Manganese (Mn) 7 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Mercury (Hg) 0.07 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Moly bdenum (Mo) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 June 2009 QTR2 Nickel (Ni) 5 mi crogram per gram (dry) (mg/g) FALSE 6761 June 2009 QTR2 Selenium (Se) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 June 2009 QTR2 Vanadium (V) 12 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

41177 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 March 2009

41177 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 March 2009

41245 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 March 2009

41245 Mercury

(Hg) 0.09 parts per million (dry) (ppm) FALSE 6761 March 2009

QTR1 Antim ony

(Sb) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 March 2009

QTR1 Arsenic (As) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 March 2009

QTR1 Barium (Ba) 445 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Bery llium (Be) 0.4 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Cadmium (Cd) 0 mi crogram per gram (dry) (mg/g) TRUE 0.2 6761 March 2009

QTR1 Chloride (Cl) 0 mi crogram per gram (dry) (mg/g) TRUE 10 6761 March 2009

QTR1 Chromium (Cr) 6 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Cobalt (Co) 1 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Copper (Cu) 9 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Fluoride (F) 62 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Lead (Pb) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 March 2009

QTR1 Manganese (Mn) 10 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Mercury

(Hg) 0.05 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Moly bdenum (Mo) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 March 2009

QTR1 Nickel (Ni) 5 mi crogram per gram (dry) (mg/g) FALSE 6761 March 2009

QTR1 Selenium (Se) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 March 2009

QTR1 Vanadium (V) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 41420 Chloride (Cl) 14 parts per million (dry) (ppm) FALSE 6761 May

2009 41420 Mercury (Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 May

2009 41488 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 May

2009 41488 Mercury (Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 May

2009 41551 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 May

2009 41551 Mercury (Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 May

2009 QTR1 Antim ony (Sb) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 May

2009 QTR1 Arsenic (As) 0 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Barium (Ba) 445 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Bery llium (Be) 0.4 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Cadmium (Cd) 0 mi crogram per gram (dry) (mg/g) TRUE 0.2 6761 May

2009 QTR1 Chloride (Cl) 0 mi crogram per gram (dry) (mg/g) TRUE 10 6761 May

2009 QTR1 Chromium (Cr) 6 mi crogram per gram (dry) (mg/g) FALSE Page 68fuel_sample_pollutants

6761 May

2009 QTR1 Cobalt (Co) 1 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Copper (Cu) 9 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Fluoride (F) 62 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Lead (Pb) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 May

2009 QTR1 Manganese (Mn) 10 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Mercury (Hg) 0.05 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Moly bdenum (Mo) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 May

2009 QTR1 Nickel (Ni) 5 mi crogram per gram (dry) (mg/g) FALSE 6761 May

2009 QTR1 Selenium (Se) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 May

2009 QTR1 Vanadium (V) 7 mi crogram per gram (dry) (mg/g) FALSE 6761 Novem ber 2009

42415 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 Novem ber 2009

42415 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 Novem ber 2009

42465 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 Novem ber 2009

42465 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 Novem ber 2009

42538 Chloride (Cl) 13 parts per million (dry) (ppm) FALSE 6761 Novem ber 2009

42538 Mercury

(Hg) 0.08 parts per million (dry) (ppm) FALSE 6761 October 2009

42238 Chloride (Cl) 16 parts per million (dry) (ppm) FALSE 6761 October 2009

42238 Mercury

(Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 October 2009

42309 Chloride (Cl) 18 parts per million (dry) (ppm) FALSE 6761 October 2009

42309 Mercury

(Hg) 0.05 parts per million (dry) (ppm) FALSE 6761 October 2009

42369 Chloride (Cl) 11 parts per million (dry) (ppm) FALSE 6761 October 2009

42369 Mercury

(Hg) 0.07 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

42055 Chloride (Cl) 0 parts per million (dry) (ppm) TRUE 10 6761 Septem ber 2009

42055 Mercury

(Hg) 0.04 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

42110 Chloride (Cl) 21 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

42110 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

42163 Chloride (Cl) 11 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

42163 Mercury

(Hg) 0.06 parts per million (dry) (ppm) FALSE 6761 Septem ber 2009

QRT3 Antim ony

(Sb) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 Septem ber 2009

QRT3 Arsenic (As) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 Septem ber 2009

QRT3 Barium (Ba) 395 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Bery llium (Be) 0.2 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Cadmium (Cd) 0 mi crogram per gram (dry) (mg/g) TRUE 0.2 6761 Septem ber 2009

QRT3 Chloride (Cl) 15 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Chromium (Cr) 6 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Cobalt (Co) 2 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Copper (Cu) 10 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Fluoride (F) 62 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Lead (Pb) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 Septem ber 2009

QRT3 Manganese (Mn) 11 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Mercury

(Hg) 0.06 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Moly bdenum (Mo) 0 mi crogram per gram (dry) (mg/g) TRUE 2 6761 Septem ber 2009

QRT3 Nickel (Ni) 5 mi crogram per gram (dry) (mg/g) FALSE 6761 Septem ber 2009

QRT3 Selenium (Se) 0 mi crogram per gram (dry) (mg/g) TRUE 1 6761 Septem ber 2009

QRT3 Vanadium (V) 13 mi crogram per gram (dry) (mg/g) FALSE

Page 69test_reports

facility _id report_id report_ty pe other_ty pe report_description report_begin_date

report_end_date

before_control

during_deviation 6761 Dec 2005 PM Compliance Test

compliance Performed by APT. Annual required EPA Method 5 Particulate Compliance Testing. ######## ######## No No 6761 Dec 2008 PM, HCL & HF Testing

compliance Performed by AirTech. Annual required EPA Method 5 Particulate Compliance testing plus HCL and HF testing to support TRI reporting. 12/3/2008 12/3/2008 No No 6761 Feb 2006 PM, HCL, and HF Testing

compliance Performed by APT. Annual required EPA Method 5 Particulate Compliance testing plus HCL and HF testing to support TRI reporting. 2/7/2006 2/7/2006 No No 6761 Nov 2007 Mercury RA Testing other Mercury

CEMS Relative Accuracy Test TRC performed mercury CEMS Relative Accuracy (RA) test. ######## ######## No No 6761 Nov 2007 PM, HCL & HF Testing

compliance Performed by APT. Annual required EPA Method 5 Particulate Compliance testing plus HCL and HF testing to support TRI reporting. 11/6/2007 11/6/2007 No No 6761 Nov 2009 PM, HCL & HF Testing

compliance Performed by AirTech. Annual required EPA Method 5 Particulate Compliance testing plus HCL and HF testing to support TRI reporting. 9/29/2009 9/29/2009 No No 6761 Oct 2006 PM, HCL & HF Testing

compliance Performed by APT. Annual required EPA Method 5 Particulate Compliance testing plus HCL and HF testing to support TRI reporting. ######## ######## No No 6761 Oct 2009 Mercury CEMS RA Test compliance TRC performed mercury CEMS Relative Accuracy (RA) test. Annual CEM RA. ######## ######## No No 6761 Sep 2008 Mercury CEMS RA Test compliance TRC performed mercury CEMS Relative Accuracy (RA) test. Initial CEM certification RA. 9/23/2008 9/23/2008 No No

Page 70test_reports

deviation_reports No No No No No No No No No

Page 71test_report_configurations

facility _id report_id configuration_id 6761 Dec 2005 PM Compliance Test

Rawhide101 6761 Dec 2008 PM, HCL & HF Testing

Rawhide101 6761 Feb 2006 PM, HCL, and HF Testing

Rawhide101 6761 Nov 2007 Mercury RA Testing Rawhide101 6761 Nov 2007 PM, HCL & HF Testing

Rawhide101 6761 Nov 2009 PM, HCL & HF Testing

Rawhide101 6761 Oct 2006 PM, HCL & HF Testing

Rawhide101 6761 Oct 2009 Mercury CEMS RA Test Rawhide101 6761 Sep 2008 Mercury CEMS RA Test Rawhide101

Page 72test_report_fuels

facility _id report_id fuel_id 6761 Dec 2005 PM Compliance Test

Coal 6761 Dec 2008 PM, HCL & HF Testing

Coal 6761 Feb 2006 PM, HCL, and HF Testing

Coal 6761 Nov 2007 Mercury RA Testing Coal 6761 Nov 2007 PM, HCL & HF Testing

Coal 6761 Nov 2009 PM, HCL & HF Testing

Coal 6761 Oct 2006 PM, HCL & HF Testing

Coal 6761 Oct 2009 Mercury CEMS RA Test Coal 6761 Sep 2008 Mercury CEMS RA Test Coal

Page 73test_report_fuel_ty pes

facility _id report_id fuel_id fuel_ty pe percentage_massvol percentage_btu

other_ty pe 6761 Dec 2005 PM Compliance Test

Coal coal - subbituminous 100 100 6761 Dec 2008 PM, HCL & HF Testing

Coal coal - subbituminous 100 100 6761 Feb 2006 PM, HCL, and HF Testing

Coal coal - subbituminous 100 100 6761 Nov 2007 Mercury RA Testing Coal coal - subbituminous 100 100 6761 Nov 2007 PM, HCL & HF Testing

Coal coal - subbituminous 100 100 6761 Nov 2009 PM, HCL & HF Testing

Coal coal - subbituminous 100 100 6761 Oct 2006 PM, HCL & HF Testing

Coal coal - subbituminous 100 100 6761 Oct 2009 Mercury CEMS RA Test Coal coal - subbituminous 100 100 6761 Sep 2008 Mercury CEMS RA Test Coal coal - subbituminous 100 100

Page 74cem_data

facility _id tim e_period

cem_period_description 6761 11/2007 - 12/2008

Mandatory

mercury reporting per Colorado's state-only rule began January

2009. Hourly

mercury monitoring data is available since November 2007.

Page 75cem_data Mandatory

mercury reporting per Colorado's state-only rule began January

2009. Hourly

mercury monitoring data is available since November 2007.

Page 76cem_data_pollutants1

facility _id tim e_period

pollutant_nam e 6761 11/2007 - 12/2008

Total Mercury

(Hgt) 6761 11/2007 - 12/2008

Elem ental Mercury

(Hg0) 6761 11/2007 - 12/2008

Oxidized Mercury

(Hg++)

Page 77test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_by pass_percent

testing_by pass_percent 6761 Dec 2005 PM Compliance Test

Stack No No 6761 Dec 2008 PM, HCL & HF Testing

Stack No No 6761 Feb 2006 PM, HCL, and HF Testing

Stack No No 6761 Nov 2007 Mercury RA Testing Stack No No 6761 Nov 2007 PM, HCL & HF Testing

Stack No No 6761 Nov 2009 PM, HCL & HF Testing

Stack No No 6761 Oct 2006 PM, HCL & HF Testing

Stack No No 6761 Oct 2009 Mercury CEMS RA Test Stack No No 6761 Sep 2008 Mercury CEMS RA Test Stack No No

Page 78test_report_sampling

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

Page 79sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 6761 Dec 2005 PM Compliance Test

Stack average ######## ######## 292.1 268.3 13.4 6761 Dec 2008 PM, HCL & HF Testing

Stack average 12/3/2008 12/3/2008 303.9 279 13.4 6761 Feb 2006 PM, HCL, and HF Testing

Stack average 2/7/2006 2/7/2006 290 265.4 12.1 6761 Nov 2007 Mercury RA Testing Stack average ######## ######## 298.4 6761 Nov 2007 PM, HCL & HF Testing

Stack average 11/6/2007 11/6/2007 297.4 273.7 12.9 6761 Nov 2009 PM, HCL & HF Testing

Stack average ######## ######## 301.9 278.3 14.7 6761 Oct 2006 PM, HCL & HF Testing

Stack 1 ######## ######## 295.8 272 13.6 6761 Oct 2006 PM, HCL & HF Testing

Stack 2 ######## ######## 291 267.2 13.9 6761 Oct 2009 Mercury CEMS RA Test Stack average ######## ######## 302 6761 Sep 2008 Mercury CEMS RA Test Stack average 9/23/2008 9/23/2008 296.2

Page 80sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 657359 dscfm 200 0.814 5.5 14.1 210 666000 dscfm 200 0.814 4.68 14.1 213 648447 dscfm 200 0.814 5.5 14 200 200 0.814 213 621799 dscfm 200 0.814 6.5 13 199 643818 dscfm 200 0.814 5.13 14.4 206 647232 dscfm 200 0.814 6.5 13.1 190 635595 dscfm 200 0.814 6.5 13 201 200 0.814 204.4 200 0.814 214.5

Page 81sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value 0.812 EPA Method 5 Coal 0.808 EPA Method 5 for PMEPA Method 202 (modified to collect HCL and HF) 0.817 EPA Method 5 for PMEPA Method 202 (modified to collect HCL and HF) 0.812 EPA Method 30B 0.807 EPA Method 5 for PMEPA Method 202 (modified to collect HCL and HF) 0.808 EPA Method 5 for PMEPA Method 202 (modified to collect HCL and HF) 0.807 EPA Method 202 (modified to collect HCL and HF) 0.815 EPA Method 5 for PM The initial 10/18/2006 PM test was invalidated due sample contamination issues. The re-test was successfully performed on 11/21/2006 and whese results are provided. 0.808 EPA Method 30B 0.819 EPM Method 30B

Page 82sampling_runs

fuel_sulfur

The initial 10/18/2006 PM test was invalidated due sample contamination issues. The re-test was successfully performed on 11/21/2006 and whese results are provided.

Page 83sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 6761 Oct 2006 PM, HCL & HF Testing

Stack 2 PM (Filterable) FALSE 6761 Nov 2007 PM, HCL & HF Testing

Stack average PM (Filterable) 15.3 mi lligram per normal cubic meter (mg/Nm3) FALSE 6761 Nov 2007 PM, HCL & HF Testing

Stack average Hydrogen Chloride (HCl) 0.24 parts per million by volum e (dry) (ppmvd) FALSE 6761 Nov 2007 PM, HCL & HF Testing

Stack average Hydrogen Fluoride (HF) 0.04 parts per million by volum e (dry) (ppmvd) FALSE 6761 Dec 2008 PM, HCL & HF Testing

Stack average PM (Filterable) 0.000715 FALSE 6761 Dec 2008 PM, HCL & HF Testing

Stack average Hydrogen Chloride (HCl) 0.284 parts per million by volum e (dry) (ppmvd) FALSE 6761 Dec 2008 PM, HCL & HF Testing

Stack average Hydrogen Fluoride (HF) 0.0997 parts per million by volum e (dry) (ppmvd) FALSE 6761 Nov 2009 PM, HCL & HF Testing

Stack average PM (Filterable) 0.001 FALSE 6761 Nov 2009 PM, HCL & HF Testing

Stack average Hydrogen Chloride (HCl) 0.02 parts per million by volum e (dry) (ppmvd) FALSE 6761 Nov 2009 PM, HCL & HF Testing

Stack average Hydrogen Fluoride (HF) 0.03 parts per million by volum e (dry) (ppmvd) FALSE 6761 Nov 2007 Mercury RA Testing Stack average Total Mercury (Hgt) 3.67 mi crogram per normal cubic meter (

FALSE 6761 Nov 2007 Mercury RA Testing Stack average Elem ental Mercury (Hg0) 1.74 mi crogram per normal cubic meter (

FALSE 6761 Nov 2007 Mercury RA Testing Stack average Oxidized Mercury (Hg++) 1.91 mi crogram per normal cubic meter (

FALSE 6761 Sep 2008 Mercury CEMS RA Test Stack average Total Mercury (Hgt) 4.43 mi crogram per normal cubic meter (

FALSE 6761 Oct 2009 Mercury CEMS RA Test Stack average Total Mercury (Hgt) 4.652 mi crogram per normal cubic meter (

FALSE 6761 Dec 2005 PM Compliance Test

Stack average PM (Filterable) 0.001 FALSE 6761 Feb 2006 PM, HCL, and HF Testing

Stack average PM (Filterable) 0.001 FALSE 6761 Feb 2006 PM, HCL, and HF Testing

Stack average Hydrogen Chloride (HCl) 0.05 parts per million by volum e (dry) (ppmvd) FALSE 6761 Feb 2006 PM, HCL, and HF Testing

Stack average Hydrogen Fluoride (HF) 0.04 parts per million by volum e (dry) (ppmvd) FALSE 6761 Oct 2006 PM, HCL & HF Testing

Stack 1 Hydrogen Chloride (HCl) 0.12 parts per million by volum e (dry) (ppmvd) FALSE 6761 Oct 2006 PM, HCL & HF Testing

Stack 1 Hydrogen Fluoride (HF) 0.21 parts per million by volum e (dry) (ppmvd) FALSE

Page 84sampling_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 FALSE FALSE 35.5 pound per hour (lb/hr)

FALSE 0.013 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.85 pound per hour (lb/hr)

FALSE 0.00032 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.07 pound per hour (lb/hr)

FALSE 0.00003 pound per million British Thermal Unit (lb/MMBtu) FALSE 17.8 pound per hour (lb/hr)

FALSE 0.00133 pound per million British Thermal Unit (lb/MMBtu) FALSE concentration measurement units are grains/dscf 1.07 pound per hour (lb/hr)

FALSE 0.000351 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.207 kilogram per hour (kg/hr)

FALSE 6.75E-05 pound per million British Thermal Unit (lb/MMBtu) FALSE 6.2 pound per hour (lb/hr)

FALSE 0.002 pound per million British Thermal Unit (lb/MMBtu) FALSE PM concentration measurement is grains/dscf 0.1 pound per hour (lb/hr)

FALSE FALSE 0.1 kilogram per hour (kg/hr)

FALSE FALSE FALSE FALSE CEMS m easured 4.01 ug/M3 FALSE FALSE CEMS m easured 2.92 ug/M3 FALSE FALSE CEMS m easured 1.09 ug/M3 FALSE FALSE CEMS m easured 4.55 ug/M3 FALSE FALSE CEMS m easured 4.866 ug/M3 3.85 pound per hour (lb/hr)

FALSE 0.001 pound per million British Thermal Unit (lb/MMBtu) FALSE The PM concentration measurement units are in grains/dscf, which are not offered as a listed Meas. Unit selection. 4.5 pound per hour (lb/hr)

FALSE 0.001 pound per million British Thermal Unit (lb/MMBtu) FALSE Concentration measurement units in gr/dscf 0.17 pound per hour (lb/hr)

FALSE 0.00006 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.09 pound per hour (lb/hr)

FALSE 0.00003 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.44 pound per hour (lb/hr)

FALSE 0.00016 pound per million British Thermal Unit (lb/MMBtu) FALSE 0.43 pound per hour (lb/hr)

FALSE 0.00015 pound per million British Thermal Unit (lb/MMBtu) FALSE

Page 85sampling_run_pollutants1 run_pollutant_comment
concentration measurement units are grains/dscf PM concentration measurement is grains/dscf CEMS m easured 4.01 ug/M3 CEMS m easured 2.92 ug/M3 CEMS m easured 1.09 ug/M3 CEMS m easured 4.55 ug/M3 CEMS m easured 4.866 ug/M3 The PM concentration measurement units are in grains/dscf, which are not offered as a listed Meas. Unit selection. Concentration measurement units in gr/dscf

Page 86sampling_run_pollutants1

The PM concentration measurement units are in grains/dscf, which are not offered as a listed Meas. Unit selection.

Page 87sampling_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 88sampling_run_fuel fuel_conc_MDL

Page 89