Facility _Information

facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_type

legal_address

legal_city legal_state legal_zip 465 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640 469 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640 470 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640 477 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640 525 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640 6248 15466 Public Service Company of Colorado Public Service Company of Colorado legal owner9500 I-76 Henderson CO 80640

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 Arapahoe 2601 S. Platte River Drive Denver CO 80223 2601 S. Platte River Drive Denver CO 80223 Cherokee 6198 Franklin Street Denver CO 80216 6198 Franklin Street Denver CO 80216 Comanche 2005 Lim e Road Pueblo CO 81006 2005 Lim e Road Pueblo CO 81006 Valm ont 1800 N. 63rd Street Boulder CO 80301 1800 N. 63rd Street Boulder CO 80301 Hayden 13125 U.S. Highway 40 Hayden CO 81639 13125 U.S. Highway 40 Hayden CO 81639 Pawnee 14940 County Road 24 Brush CO 80723 14940 County Road 24 Brush CO 80723

Page 2Facility _Information

RFA_small_entity

ff_fired_coal

ff_fired_oil ff_fired_ngas ff_fired_petcoke

ff_fired_other

ff_permitted_coal

ff_permitted_oil

ff_permitted_ngas No TRUE FALSE TRUE FALSE FALSE TRUE FALSE TRUE No TRUE FALSE TRUE FALSE FALSE TRUE FALSE TRUE No TRUE FALSE TRUE FALSE FALSE TRUE FALSE TRUE No TRUE FALSE TRUE FALSE FALSE TRUE FALSE TRUE No TRUE TRUE TRUE FALSE FALSE TRUE TRUE TRUE No TRUE FALSE TRUE FALSE FALSE TRUE FALSE TRUE

Page 3Facility _Information

ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note FALSE FALSE There are no mercury permit requirements in place at this time for this unit. No Not Applicable The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r FALSE FALSE Beginning 1-1-2014 a mercury lim it for this unit will go into place. Deviaitions of the limit will be reported in the semi annual and annual Title V compliance reports. No Colorado Department of Public Health and Environment The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 FALSE FALSE Beginning January 2012 a mercury

lim it for this unit will go into place. Deviaitions of the limit will be reported in the semi annual and annual Title V compliance reports. No Colorado Department of Public Health and Environment Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u FALSE FALSE Beginning 1-1-2014 a mercury lim it for this unit will go into place. Deviaitions of the limit will be reported in the semi annual and annual Title V compliance reports. No Colorado Department of Public Health and Environment The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi FALSE FALSE Beginning 1-1-2014 a mercury lim it for this unit will go into place. Deviaitions of the limit will be reported in the semi annual and annual Title V compliance reports. No Colorado Department of Public Health and Environment This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. FALSE FALSE Beginning 1-1-2012 a mercury lim it for this unit will go into place. Deviaitions of the limit will be reported in the semi annual and annual Title V compliance reports. No Colorado Department of Public Health and Environment The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 4Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 5Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 6Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 7Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 8Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 9Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 10Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 11Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing. The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-The data entryscreen would not allow m e to enter the actual "Flue gas temperature" of 326 F, so a value of "0" was entered for the PAW 1 Hg Aug05 test. For the PAW 1 Hg Oct07 test the actual temperature was 316 F. For the PAW 1 Hg Jul08 test the actual temp was 344 F.-No fuel analysis was collected during testing.

Page 12Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing.

Page 13Facility _Information

The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for both Arapahoe Units 3 and 4. Note that these units do share a common stack. This facility does not have any

HAP-specific emissions control technology.The sampling ports for both Arapahoe units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Arapahoe Units 3 and 4 are part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Cherokee Units 1, 2, 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.The Boiler Information for steam r The information on the Stack Diameter given in Facility Unit Configuration under Equipment Details is actually the diam eter of the duct. The flow and gas emissions are measured in the duct and not on the stack for each of the four Cherokee units.This facility does not have any

HAP-specific emissions control technology.The sampling ports for all four Cherokee units are located on the duct. The ports are arranged vertically with the port assinged SP01 being at the base of the duct.Cherokee Units 1, 2, 3 and 4 are all part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Valmont Unit 5). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.All of the Cherokee units burned some coal from the Colowyo mine in 2007 Comanche Unit 3 is a new unit that did not start operation until 1-11-10. As such, many of the questions requesting information for current operations are not available.The SCR NOx controls for Unit 3 is projected to go into service March 2010. The entry field under NOx controls in the Facility Unit Configuration would not allow this date to be entered.The Baghouse PM controls for Unit 3 went into service January 2010. The entry

field under PM controls in the Facility Unit Configuration would not allow this date to be entered.The Spray Dryer Type SO2 controls for Unit 3 is projected to go into service March 2010. The entry field under SO2 controls in the Facility Unit Configuration would not allow this date to be entered.The Activated Carbon Injection Hg controls for Units 1, 2 and 3 are projected to go into service March 2010. The entry field under Other controls in the Facility Unit Configuration would not allow this date to be entered. As part of the Unit 3 construction permit, these u The unit burned some coal from the Colowyo mine in 2007 and 2008. In 2007 the Colowyo coal accounted for 22.76% of the total 97.85% Btu generated by coal. In 2008 the Colowyo coal accounted for 11.17% of the total 99.72% Btu generated by coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn.Valmont Unit 5 is part of a voluntary emissions reduction agreement that includes other PSCo generating units located in the Denver Metro Area (Arapahoe Units 3 & 4 and Cherokee Units 1,2,3 and 4). Combined on an annual basis these units can emit no more than a total of 10,500 tons of SO2. Compliance with the agreement can be also demonstrated by achieving a m inim umof 70% SO2 emissions removal from all units combined on an annual basis.This facility does not have any

HAP-specific emissions control technology.The Fuel Shipment Information gi This facility

does not have any

HAP-specific emissions control technology.Both Hayden units burned some coal from the Colowyo mine in 2007. In 2007 the Colowyo coal accounted for 12.712% of the total 99.766% Btu generated by coal in Unit 1. For Unit 2 12.73% of the total 99.93% of the Btu's generated by coal was from Colowyp coal. For reporting information to the ICR the Colowyo coal was treated as a bituminous coal given its characteristics.The Fuel Shipment Information given is based on monthly coal deliveries and is seperated by mine. The sulfur, ash and higher heating values given are based on a weighted averages from the individual monthly mine deliveries.Test Report Emission Data:-Note that the information reported for emissions testing programs is given as the average of the individual runs. Since each run is made up of information collected at each sample port, the sample point selected was just the stack.-No fuel analysis was collected during testing.

Page 14facility _contacts

facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 465 1 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE 469 2 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE 470 3 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE 477 6 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE 525 4 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE 6248 5 Environm ental Analyst Chad Campbell

7204972111 chad.campbell@xcelenergy.com TRUE

Page 15facility _coal_utilized

facility _id coal_type percentage_mass percentage_btu

synfuel_type

coal_note 465 subbituminous 100 100 469 bitum inous 96.42 96.77 469 subbituminous 3.58 3.23 470 subbituminous 100 100 477 bitum inous 61.18 66.69 477 subbituminous 38.82 33.31 In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn. The normal coal ranking for this unit is bituminous. 525 bitum inous 100 100 6248 subbituminous 100 100

Page 16facility _coal_utilized

In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn. The normal coal ranking for this unit is bituminous.

Page 17facility _coal_utilized

In 2009 the unit burned some subbituminous coal from the Black Thunder mine as part of a test burn. The normal coal ranking for this unit is bituminous.

Page 18facility _oil_utilized

facility _id oil_type percentage_volume percentage_btu

other_type 525 No.2 Fuel Oil (distillate) 100 100

Page 19facility _other_materials

facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain

Page 20facility _other_materials

rcra_explain

Page 21boiler_information

facility _id boiler_id boiler_type boiler_other bottom_design

design_fuelheat_input max_heat_input MW e_capacity 465 3 Vertical firing Dry Bottom coal 754.8 754.8 48 465 4 Vertical firing Dry Bottom coal 1709.4 1709.4 118 469 1 Vertical firing Dry Bottom coal 1392 1392 117 469 2 Vertical firing Dry Bottom coal 1392 1392 114 469 3 Wa ll firing - front firing Dry Bottom coal 1877 1877 165 469 4 Tangential firing Dry Bottom coal 3520 3520 383 470 1 Tangential firing Dry Bottom coal 3531 3531 360 470 2 Wa ll firing - front firing Dry Bottom coal 3482 3482 365 470 3 Tangential firing Dry Bottom coal 7421 7421 838 477 5 Tangential firing Dry Bottom coal 1845 1845 196 525 1 Wa ll firing - front firing Dry Bottom coal 1963 1963 202 525 2 Tangential firing Dry Bottom coal 2712 2712 285 6248 1 Wa ll firing - opposed firing Dry Bottom coal 5346 5346 536

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 44 84.6 84.8 1050 865 905 900 FALSE 109 85.97 84.9 1687 1450 1005 1000 FALSE 107 86.33 86.4 1523 1520 1005 933 FALSE 1005 106 86.39 86.2 1519 1500 1005 933 FALSE 1005 152 87.69 86.7 1890 1895 1006 1006 FALSE 1005 352 88.29 87.4 2520 2500 1000 1000 FALSE 1000 325 84.65 84.9 2850 2645 1005 990 FALSE 1005 335 84.57 85 2800 2550 1005 1000 FALSE 1005 788 87.57 3920 3732 1055 1055 FALSE 1105 184 86.66 86.66 1800 1800 1005 1000 FALSE 1005 184 87.8 84.2 2225 1990 1005 1001 FALSE 1005 262 88.22 85.7 2330 1990 1005 1003 FALSE 1005 505 84.87 83.7 2800 2620 1005 1005 FALSE 1005

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 7213 66.98 N 2014 FALSE FALSE 7144 66.79 N 2014 FALSE FALSE 940 6330.42 59.99 N 2017 FALSE FALSE 950 6352.73 61.67 N 2019 FALSE FALSE 976 7714.1 69.78 N 2022 FALSE FALSE 1000 7252.49 69.15 N 2028 FALSE FALSE 968 7521.23 76.7 N 2033 FALSE FALSE 980 7627.5 79.41 Subpart D 2035 FALSE FALSE 1105 Subpart Da(1) FALSE FALSE 996 7235 74.7 N 2024 FALSE FALSE 1001 7978.29 85.47 N 2025 FALSE FALSE 1003 8123.42 88.32 Subpart D 2036 FALSE FALSE 1005 7226 71.58 Subpart D 2041 FALSE

Page 24boiler_information

NOx_control

SO2_control

combustion_additives No 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 Yes Yes No Yes Yes No

Page 25boiler_fuels

facility _id boiler_id fuel_type fuel_year percentage_massvol percentage_btu

other_type 465 3 coal - subbituminous 2007 0 90.71 465 3 coal - subbituminous 2008 0 99.64 465 3 coal - subbituminous 2009 0 99.6 465 3 natural gas 2007 0 9.29 465 3 natural gas 2008 0 0.36 465 3 natural gas 2009 0 0.4 465 4 coal - subbituminous 2007 0 92.7 465 4 coal - subbituminous 2008 0 99.74 465 4 coal - subbituminous 2009 0 99.39 465 4 natural gas 2007 0 7.3 465 4 natural gas 2008 0 0.26 465 4 natural gas 2009 0 0.61 469 1 coal - bituminous2007 0 98.45 469 1 coal - bituminous2008 0 98.62 469 1 coal - bituminous2009 0 99.27 469 1 natural gas 2007 0 1.55 469 1 natural gas 2008 0 1.38 469 1 natural gas 2009 0 0.73 469 2 coal - bituminous2007 0 93.19 469 2 coal - bituminous2008 0 99.46 469 2 coal - bituminous2009 0 99.3 469 2 natural gas 2007 0 6.81 469 2 natural gas 2008 0 0.54 469 2 natural gas 2009 0 0.7 469 3 coal - bituminous2007 0 86.35 469 3 coal - bituminous2008 0 95.08 469 3 coal - bituminous2009 0 93.07 469 3 natural gas 2007 0 13.65 469 3 natural gas 2008 0 4.92 469 3 natural gas 2009 0 6.93 469 4 coal - bituminous2007 0 97.87 469 4 coal - bituminous2008 0 99.53 469 4 coal - bituminous2009 0 98.97 469 4 natural gas 2007 0 2.13 469 4 natural gas 2008 0 0.47 469 4 natural gas 2009 0 1.03 470 1 coal - subbituminous 2007 0 99.71 470 1 coal - subbituminous 2008 0 99.42 470 1 coal - subbituminous 2009 0 98.69 470 1 natural gas 2007 0 0.29 470 1 natural gas 2008 0 0.58 470 1 natural gas 2009 0 1.31 470 2 coal - subbituminous 2007 0 99.58 470 2 coal - subbituminous 2008 0 99.66 470 2 coal - subbituminous 2009 0 98.77 470 2 natural gas 2007 0 0.42 470 2 natural gas 2008 0 0.34 470 2 natural gas 2009 0 1.23 477 5 coal - bituminous2007 0 97.85 477 5 coal - bituminous2008 0 99.72 477 5 coal - bituminous2009 0 66.5

Page 26boiler_fuels

477 5 coal - subbituminous 2009 0 33.2 477 5 natural gas 2007 0 2.15 477 5 natural gas 2008 0 0.28 477 5 natural gas 2009 0 0.3 525 1 coal - bituminous2007 0 99.77 525 1 coal - bituminous2008 0 99.92 525 1 coal - bituminous2009 0 99.8 525 1 natural gas 2007 0 0.23 525 1 natural gas 2008 0 0.08 525 1 natural gas 2009 0 0.2 525 1 oil - distillate 2007 0 0 525 1 oil - distillate 2008 0 0 525 1 oil - distillate 2009 0 0 525 2 coal - bituminous2007 99.93 525 2 coal - bituminous2008 99.9 525 2 coal - bituminous2009 99.93 525 2 oil - distillate 2007 0.07 525 2 oil - distillate 2008 0.1 525 2 oil - distillate 2009 0.07 6248 1 coal - subbituminous 2007 0 99.4 6248 1 coal - subbituminous 2008 0 99.74 6248 1 coal - subbituminous 2009 0 99.31 6248 1 natural gas 2007 0 0.6 6248 1 natural gas 2008 0 0.26 6248 1 natural gas 2009 0 0.69

Page 27boiler_control_NOx

facility _id boiler_id NOx_type NOx_other NOx_online 465 4 Low NOx Burner 5/1/1992 465 4 Overfire Air 5/1/1992 469 1 Low NOx Burner 12/1/1998 469 1 Overfire Air 12/1/1998 469 2 Overfire Air 6/1/1999 469 3 Low NOx Burner 10/1/1991 469 3 Overfire Air 10/1/1991 469 4 Low NOx Burner 11/1/1990 469 4 Overfire Air 11/1/1990 470 1 Low NOx Burner 11/1/2008 470 1 Overfire Air 11/1/2008 470 2 Low NOx Burner 11/1/2007 470 2 Overfire Air 11/1/2007 470 3 Low NOx Burner 1/1/2010 470 3 Overfire Air 1/1/2010 477 5 Low NOx Burner 5/1/1990 477 5 Overfire Air 5/1/1990 525 1 Low NOx Burner 12/1/1988 525 1 Overfire Air 12/1/1988 525 2 Low NOx Burner 6/1/1990 525 2 Overfire Air 6/1/1990 6248 1 Low NOx Burner 12/1/1994 6248 1 Overfire Air 12/1/1994

Page 28boiler_control_SO2

facility _id boiler_id SO2_type SO2_other SO2_online 465 3 Low Sulfur Coal 11/1/1951 465 4 Low Sulfur Coal 8/1/1955 469 1 Low Sulfur Coal 8/1/1957 469 2 Low Sulfur Coal 5/1/1959 469 3 Low Sulfur Coal 4/1/1962 469 4 Low Sulfur Coal 11/1/1968 470 1 Low Sulfur Coal 12/1/1973 470 2 Low Sulfur Coal 11/1/1975 470 3 Low Sulfur Coal 1/1/2010 477 5 Low Sulfur Coal 5/1/1964 525 1 Low Sulfur Coal 7/1/1965 525 2 Low Sulfur Coal 11/1/1976 6248 1 Low Sulfur Coal 11/1/1981

Page 29boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online

Page 30facility _units

facility _id unit_id 465 3 465 4 469 1 469 2 469 3 469 4 470 1 470 2 470 3 477 5 525 1 525 2 6248 1

Page 31unit_boilers

facility _id unit_id boiler_id 465 3 3 465 4 4 469 1 1 469 2 2 469 3 3 469 4 4 470 1 1 470 2 2 470 3 3 477 5 5 525 1 1 525 2 2 6248 1 1

Page 32facility _controls

facility _id control_id control_group control_type

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 465 BH3 PM control Fabric Filter, reverse air FALSE 6/1/1979 465 BH4 PM control Fabric Filter, reverse air FALSE 4/1/1985 465 DSI3 SO2 control Other (specify)

Dry SodiumInjection

FALSE 12/1/2002 465 DSI4 SO2 control Other (specify)

Dry SodiumInjection

FALSE 6/1/1993 469 BH1 PM control Fabric Filter, reverse air FALSE 9/1/1989 469 BH2 PM control Fabric Filter, reverse air FALSE 5/1/1985 469 BH3 PM control Fabric Filter, reverse air FALSE 2/1/1988 469 BH4 PM control Fabric Filter, reverse air FALSE 4/1/1989 469 DSI1 SO2 control Other (specify)

Dry SodiumInjection

FALSE 2/1/1998 469 DSI2 SO2 control Other (specify)

Dry SodiumInjection

FALSE 12/1/2002 469 LSD3 SO2 control Spray dryer type FALSE 6/1/2002 469 LSD4 SO2 control Spray dryer type FALSE 10/1/2002 470 ACI1 Other control Activated carbon injection FALSE 470 ACI2 Other control Activated carbon injection FALSE 470 ACI3 Other control Activated carbon injection FALSE 470 BH1 PM control Fabric Filter, reverse air FALSE 11/1/1990 470 BH2 PM control Fabric Filter, reverse air FALSE 12/1/1991 470 BH3 PM control Fabric Filter, pulse FALSE 470 LSD1 SO2 control Spray dryer type FALSE 12/1/2008 470 LSD2 SO2 control Spray dryer type FALSE 7/1/2008 470 LSD3 SO2 control Spray dryer type FALSE 470 SCR3 NOx control Selective Cataly

tic Reduction FALSE Am monia 477 BH5 PM control Fabric Filter, reverse air FALSE 4/1/1984 477 LSD5 SO2 control Spray dryer type FALSE 4/1/2002 525 BH1 PM control Fabric Filter, reverse air FALSE 12/1/1998 525 BH2 PM control Fabric Filter, reverse air FALSE 6/1/1999 525 LSD1 SO2 control Spray dryer type FALSE 12/1/1998 525 LSD2 SO2 control Spray dryer type FALSE 6/1/1999 6248 BH1 PM control Fabric Filter, reverse air FALSE 11/1/1981

Page 33facility _controls

reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive

Other (specify)

SodiumSesquicarbonate

No Other (specify)

SodiumSesquicarbonate

No

Other (specify)

SodiumSesquicarbonate

No Other (specify)

SodiumSesquicarbonate

No Lim e and alkaline fly

ash No Lim e and alkaline fly

ash No

Lim e and alkaline fly

ash No Lim e and alkaline fly

ash No Lim e and alkaline fly

ash No 19

Lim e and alkaline fly ash No

Lim e and alkaline fly

ash No Lim e and alkaline fly

ash No

Page 34facility _sampling_ports

facility _id sampling_port_id 465 SP01U3 465 SP01U4 465 SP02U3 465 SP02U4 465 SP03U3 465 SP03U4 465 SP04U3 465 SP04U4 465 SP05U3 465 SP05U4 465 SP06U3 465 SP06U4 465 SP07U3 465 SP07U4 465 SP08U3 465 SP08U4 469 SP01U1 469 SP01U2 469 SP01U3 469 SP01U4 469 SP02U1 469 SP02U2 469 SP02U3 469 SP02U4 469 SP03U1 469 SP03U2 469 SP03U3 469 SP03U4 469 SP04U1 469 SP04U2 469 SP04U3 469 SP04U4 469 SP05U1 469 SP05U2 469 SP05U3 469 SP05U4 469 SP06U1 469 SP06U2 469 SP06U3 469 SP06U4 469 SP07U1 469 SP07U4 469 SP08U1 469 SP08U4 470 SP01U1 470 SP01U2 470 SP01U3 470 SP02U1 470 SP02U2 470 SP02U3 470 SP03U1

Page 35facility _sampling_ports

470 SP03U2 470 SP03U3 470 SP04U1 470 SP04U2 470 SP04U3 470 SP05U1 470 SP05U2 470 SP05U3 470 SP06U3 477 SP01U5 477 SP02U5 477 SP03U5 477 SP04U5 525 SP01U1 525 SP01U2 525 SP02U1 525 SP02U2 525 SP03U1 525 SP03U2 525 SP04U1 525 SP04U2 6248 SP01U1 6248 SP02U1 6248 SP03U1 6248 SP04U1

Page 36facility _stacks

facility _id stack_id stack_height stack_diameter

sack_gas_velocity 465 Stack3 250 12 42.82 465 Stack4 250 12.34 47.98 469 Stack1 300 13.99 53.49 469 Stack2 300 13.62 54.86 469 Stack3 300 13.31 69.72 469 Stack4 400 26.06 38.32 470 Stack1 500 23.41 47.14 470 Stack2 500 23.41 56.38 470 Stack3 500 30.5 73.17 477 Stack5 250 22.17 32.78 525 Stack1 250 22.92 35.46 525 Stack2 395 24.25 35.89 6248 Stack1 550 24.83 61.5

Page 37configurations

facility _id configuration_id 465 Unit 3 465 Unit 4 469 Unit 1 469 Unit 2 469 Unit 3 469 Unit 4 470 Unit 1 470 Unit 2 470 Unit 3 477 Unit 5 525 Unit 1 525 Unit 2 6248 Unit 1

Page 38configuration_components

facility _id configuration_id

component_id

order component_type port_near 465 Unit 3 3 1 Unit 465 Unit 3 BH3 3 PM control 465 Unit 3 DSI3 2 SO2 control 465 Unit 3 SP01U3 4 Sam pling Port pevious 465 Unit 3 SP02U3 5 Sam pling Port pevious 465 Unit 3 SP03U3 6 Sam pling Port pevious 465 Unit 3 SP04U3 7 Sam pling Port pevious 465 Unit 3 SP05U3 8 Sam pling Port pevious 465 Unit 3 SP06U3 9 Sam pling Port pevious 465 Unit 3 SP07U3 10 Sam pling Port pevious 465 Unit 3 SP08U3 11 Sam pling Port pevious 465 Unit 3 Stack3 12 Stack 465 Unit 4 4 1 Unit 465 Unit 4 BH4 3 PM control 465 Unit 4 DSI4 2 SO2 control 465 Unit 4 SP01U4 4 Sam pling Port pevious 465 Unit 4 SP02U4 5 Sam pling Port pevious 465 Unit 4 SP03U4 6 Sam pling Port pevious 465 Unit 4 SP04U4 7 Sam pling Port pevious 465 Unit 4 SP05U4 8 Sam pling Port pevious 465 Unit 4 SP06U4 9 Sam pling Port pevious 465 Unit 4 SP07U4 10 Sam pling Port pevious 465 Unit 4 SP08U4 11 Sam pling Port pevious 465 Unit 4 Stack4 12 Stack 469 Unit 1 1 1 Unit 469 Unit 1 BH1 3 PM control 469 Unit 1 DSI1 2 SO2 control 469 Unit 1 SP01U1 4 Sam pling Port pevious 469 Unit 1 SP02U1 5 Sam pling Port pevious 469 Unit 1 SP03U1 6 Sam pling Port pevious 469 Unit 1 SP04U1 7 Sam pling Port pevious 469 Unit 1 SP05U1 8 Sam pling Port pevious 469 Unit 1 SP06U1 9 Sam pling Port pevious 469 Unit 1 SP07U1 10 Sam pling Port pevious 469 Unit 1 SP08U1 11 Sam pling Port pevious 469 Unit 1 Stack1 12 Stack 469 Unit 2 1 1 Unit 469 Unit 2 BH2 3 PM control 469 Unit 2 DSI2 2 SO2 control 469 Unit 2 SP01U2 4 Sam pling Port pevious 469 Unit 2 SP02U2 5 Sam pling Port pevious 469 Unit 2 SP03U2 6 Sam pling Port pevious 469 Unit 2 SP04U2 7 Sam pling Port pevious 469 Unit 2 SP05U2 8 Sam pling Port pevious 469 Unit 2 SP06U2 9 Sam pling Port pevious 469 Unit 2 Stack2 10 Stack 469 Unit 3 3 1 Unit 469 Unit 3 BH3 3 PM control 469 Unit 3 LSD3 2 SO2 control 469 Unit 3 SP01U3 4 Sam pling Port pevious 469 Unit 3 SP02U3 5 Sam pling Port pevious

Page 39configuration_components

469 Unit 3 SP03U3 6 Sam pling Port pevious 469 Unit 3 SP04U3 7 Sam pling Port pevious 469 Unit 3 SP05U3 8 Sam pling Port pevious 469 Unit 3 SP06U3 9 Sam pling Port pevious 469 Unit 3 Stack3 10 Stack 469 Unit 4 4 1 Unit 469 Unit 4 BH4 3 PM control 469 Unit 4 LSD4 2 SO2 control 469 Unit 4 SP01U4 4 Sam pling Port pevious 469 Unit 4 SP02U4 5 Sam pling Port pevious 469 Unit 4 SP03U4 6 Sam pling Port pevious 469 Unit 4 SP04U4 7 Sam pling Port pevious 469 Unit 4 SP05U4 8 Sam pling Port pevious 469 Unit 4 SP06U4 9 Sam pling Port pevious 469 Unit 4 SP07U4 10 Sam pling Port pevious 469 Unit 4 SP08U4 11 Sam pling Port pevious 469 Unit 4 Stack4 12 Stack 470 Unit 1 1 1 Unit 470 Unit 1 ACI1 2 Other control 470 Unit 1 BH1 4 PM control 470 Unit 1 LSD1 3 SO2 control 470 Unit 1 SP01U1 5 Sam pling Port next 470 Unit 1 SP02U1 6 Sam pling Port next 470 Unit 1 SP03U1 7 Sam pling Port next 470 Unit 1 SP04U1 8 Sam pling Port next 470 Unit 1 SP05U1 9 Sam pling Port next 470 Unit 1 Stack1 10 Stack 470 Unit 2 2 1 Unit 470 Unit 2 ACI2 2 Other control 470 Unit 2 BH2 4 PM control 470 Unit 2 LSD2 3 SO2 control 470 Unit 2 SP01U2 5 Sam pling Port next 470 Unit 2 SP02U2 6 Sam pling Port next 470 Unit 2 SP03U2 7 Sam pling Port next 470 Unit 2 SP04U2 8 Sam pling Port next 470 Unit 2 SP05U2 9 Sam pling Port next 470 Unit 2 Stack2 10 Stack 470 Unit 3 3 1 Unit 470 Unit 3 ACI3 3 Other control 470 Unit 3 BH3 5 PM control 470 Unit 3 LSD3 4 SO2 control 470 Unit 3 SCR3 2 NOx control 470 Unit 3 SP01U3 6 Sam pling Port next 470 Unit 3 SP02U3 7 Sam pling Port next 470 Unit 3 SP03U3 8 Sam pling Port next 470 Unit 3 SP04U3 9 Sam pling Port next 470 Unit 3 SP05U3 10 Sam pling Port next 470 Unit 3 SP06U3 11 Sam pling Port next 470 Unit 3 Stack3 12 Stack 477 Unit 5 5 1 Unit 477 Unit 5 BH5 3 PM control 477 Unit 5 LSD5 2 SO2 control

Page 40configuration_components

477 Unit 5 SP01U5 4 Sam pling Port next 477 Unit 5 SP02U5 5 Sam pling Port next 477 Unit 5 SP03U5 6 Sam pling Port next 477 Unit 5 SP04U5 7 Sam pling Port next 477 Unit 5 Stack5 8 Stack 525 Unit 1 1 1 Unit 525 Unit 1 BH1 3 PM control 525 Unit 1 LSD1 2 SO2 control 525 Unit 1 SP01U1 4 Sam pling Port next 525 Unit 1 SP02U1 5 Sam pling Port next 525 Unit 1 SP03U1 6 Sam pling Port next 525 Unit 1 SP04U1 7 Sam pling Port next 525 Unit 1 Stack1 8 Stack 525 Unit 2 2 1 Unit 525 Unit 2 BH2 3 PM control 525 Unit 2 LSD2 2 SO2 control 525 Unit 2 SP01U2 4 Sam pling Port next 525 Unit 2 SP02U2 5 Sam pling Port next 525 Unit 2 SP03U2 6 Sam pling Port next 525 Unit 2 SP04U2 7 Sam pling Port next 525 Unit 2 Stack2 8 Stack 6248 Unit 1 1 1 Unit 6248 Unit 1 BH1 2 PM control 6248 Unit 1 SP01U1 3 Sam pling Port next 6248 Unit 1 SP02U1 4 Sam pling Port next 6248 Unit 1 SP03U1 5 Sam pling Port next 6248 Unit 1 SP04U1 6 Sam pling Port next 6248 Unit 1 Stack1 7 Stack

Page 41configuration_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_2 469 Unit 2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 10500 tons per year (tons/yr) 469 Unit 3 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 469 Unit 3 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 10500 tons per year (tons/yr) 469 Unit 3 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.46 pound per million British Thermal Unit (lb/MMBtu) 469 Unit 4 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 469 Unit 4 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.88 pound per million British Thermal Unit (lb/MMBtu) 469 Unit 4 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.4 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 470 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.12 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 1 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

Annual 0.2 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 2 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 470 Unit 2 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.46 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.12 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 3 PM (Filterable) State - State Operating Permit

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

Continuous 470 Unit 3 Total PM (Filterable and Condensable) State - State Operating Permit

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

Continuous 715 tons per year (tons/yr) 470 Unit 3 PM10 (Filterable) State - State Operating Permit

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

Continuous 470 Unit 3 Total PM10 (Filterable and Condensable) State - State Operating Permit

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

Continuous 470 Unit 3 Carbon Monoxide (CO) State - State Operating Permit

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

8 hours 0.3 pound per million British Thermal Unit (lb/MMBtu) 465 Unit 4 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 465 Unit 4 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.88 pound per million British Thermal Unit (lb/MMBtu) 465 Unit 4 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.8 pound per million British Thermal Unit (lb/MMBtu) 469 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 469 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.88 pound per million British Thermal Unit (lb/MMBtu) 469 Unit 1 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.8 pound per million British Thermal Unit (lb/MMBtu) 469 Unit 2 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 465 Unit 3 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

Annual 469 Unit 2 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

Annual 470 Unit 3 Sulfur Dioxide (SO2) State - State Operating Permit

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

3 hours 1.4 pound per Megawatt hour (lb/MW h) 470 Unit 3 Nitrogen Oxide (NOx) State - State Operating Permit

1 pound per Megawatt hour (lb/MW h)

30 days 0.08 pound per million British Thermal Unit (lb/MMBtu) 470 Unit 3 Total Mercury (Hgt) State - State Operating Permit

1.47E-05 pound per Megawatt hour (lb/MW h)

Annual 470 Unit 3 VOCs State - State Operating Permit 0.0035 pound per million British Thermal Unit (lb/MMBtu)

Continuous 470 Unit 3 Hydrogen Chloride (HCl) State - State Operating Permit

0.0062 pound per million British Thermal Unit (lb/MMBtu)

Continuous 470 Unit 3 Hydrogen Fluoride (HF) State - State Operating Permit

0.0004 pound per million British Thermal Unit (lb/MMBtu)

Continuous 470 Unit 3 Sulfur Trioxide (H2SO4) State - State Operating Permit

0.0042 pound per million British Thermal Unit (lb/MMBtu)

Continuous 525 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 525 Unit 1 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

Annual 525 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.16 pound per million British Thermal Unit (lb/MMBtu) 465 Unit 3 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 465 Unit 3 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 10500 tons per year (tons/yr) 525 Unit 2 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 525 Unit 2 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

3 hours 0.4 pound per million British Thermal Unit (lb/MMBtu) 525 Unit 2 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 0.16 pound per million British Thermal Unit (lb/MMBtu) 6248 Unit 1 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 6248 Unit 1 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

3 hours 0.46 pound per million British Thermal Unit (lb/MMBtu) 6248 Unit 1 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 477 Unit 5 PM (Filterable) Fderal - Title V Operating Permit

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

Continuous 477 Unit 5 Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

30 days 0.4 pound per million British Thermal Unit (lb/MMBtu) 477 Unit 5 Sulfur Dioxide (SO2) Federal - Title V Operating Permit

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

3 hours 10500 tons per year (tons/yr)

Page 42configuration_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 Annual Cherokee Unit 2 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual Cherokee Unit 3 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). Annual The actual 30-day NOx limit for Cherokee Unit 3 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu.

30 days 20 percent by weight Annual 10500 tons per year (tons/yr) Annual 0.88 lb/m mbtu SO2 limit from Nov 1 to Mar 1. Unit 4 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of VERP(See Note section). Units 1&4 combined must meet an annual % removal of 20%. Annual The actual 30-day NOx limit for Cherokee Unit 4 is 0.40 lb/mmbtu. The data entry screen cuts it to 0.4 lb/mmbtu. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test 30 days 0.1 pound per million British Thermal Unit (lb/MMBtu) Annual Comanche Units 1 & 2 share the 0.10 lb/mmbtu annual limit. The emissions from the units combined shall not exceed 0.10 lb/mmbtu on an annual rolling average. Note that the limit is 0.10, the data entryscreen only allowed 0.1 to be entered. 30 days 0.15 pound per million British Thermal Unit (lb/MMBtu) Annual The 30-day lim it is 0.20 but the data entry only allowed for 0.2. The annual limit is 0.40 but data entry only allowed 0.4. Units 1 & 2 share the 0.15 lb/mmbtu annual limit. Combined shall not exceed 0.15 lb/mmbtu on an annual rolling average. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual 0.2 pound per million British Thermal Unit (lb/MMBtu) 30 days 0.15 pound per million British Thermal Unit (lb/MMBtu) Annual The 30-day lim it is 0.20 but the data entry only allowed for 0.2. Units 1 & 2 share the 0.15 lb/mmbtu annual limit. Combined shall not exceed 0.15 lb/mmbtu on an annual rolling average. 30 days 0.1 pound per million British Thermal Unit (lb/MMBtu) Annual Comanche Units 1 & 2 share the 0.10 lb/mmbtu annual limit. The emissions from the units combined shall not exceed 0.10 lb/mmbtu on an annual rolling average. Note that the limit is 0.10, the data entryscreen only allowed 0.1 to be entered. Compliance based on annual stack testing. The limit is 0.0130 lb/mmbtu but the data entry only allowed 0.013. Performance Test Annual Compliance based on annual stack testing. Compliance based on annual stack testing. The limit is 0.0120 lb/mmbtu but the data entry only allowed 0.012. Performance Test Compliance based on annual stack testing. The limit is 0.020 lb/mmbtu but the data entry only allowed 0.02. 8 hours The CO limit for normal operation is 0.13 lb/mmbtu 8-hr rolling avg. The CO startup limit is 0.30 lb/mmbtu averaged over the duration of the startup event or 8-hrs, whichever is shorter. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test 30 days 20 percent by weight Annual 10500 tons per year (tons/yr) Annual Arapahoe Unit 4 is required to meet an annual 20% SO2 removal requirement.Arapahoe Unit 4 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). Annual The actual 30-day NOx limit for Arapahoe Unit 4 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu.Arapahoe Units 3 & 4 have an averaging plan for the Part 76 annual NOx rate limit. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test 30 days 20 percent by weight Annual 10500 tons per year (tons/yr) Annual 0.88 lb/m mbtu SO2 limit from Nov 1 to Mar 1. Unit 1 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of VERP(See Note section). Units 1&4 combined must meet an annual % removal of 20%. Annual The actual 30-day NOx limit for Cherokee Unit 1 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu.Cherokee Units 1 & 2 have an averaging plan for the Part 76 annual NOx rate limit. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Arapahoe Units 3 & 4 have an averaging plan for the Part 76 annual NOx rate limit. Cherokee Units 1 & 2 have an averaging plan for the Part 76 annual NOx rate limit. 30 days 0.1 pound per million British Thermal Unit (lb/MMBtu) 30 days The 30-day lb/m mbtu lim it is 0.10 but the data entry lim ited it to 0.1. 30 days 0.07 pound per million British Thermal Unit (lb/MMBtu) Annual The 30-day lb/MW hr lim it is 1.0 lb/mmbtu. The data entry screen limits it to 1. The annual limit is an annual rolling average limit. The Hg limit is a 12-month rolling average. Compliance based on annual stack testing. Compliance based on annual stack testing. Compliance based on annual stack testing. The HF limit is 0.00040 but the data entry screen limited it to 0.0004. Compliance based on annual stack testing. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test

30 days 0.13 pound per million British Thermal Unit (lb/MMBtu) 90 days 82 percent by weight 30 days The 30-day lim it is 0.160 lb/mmbtu and the data entry screen only

allowed 0.16. The 90-day lim it is 0.130 lb/mmbtu and the data entry screen only

allowed 0.13. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual Arapahoe Unit 3 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual The 3-hour limit is 0.70 lb/mmbtu and the data entry screen only

allowed 0.7. The 90-day lim it is 0.40 lb/mmbtu and the data entry screen only

allowed 0.4. 30 days 0.13 pound per million British Thermal Unit (lb/MMBtu) 90 days 82 percent by weight 30 days The 30-day lim it is 0.160 lb/mmbtu and the data entry screen only

allowed 0.16. The 90-day lim it is 0.130 lb/mmbtu and the data entry screen only

allowed 0.13. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual

Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Performance Test Annual The annual limit is 0.40 but data entry only allowed 0.4. Annual Valm ont Unit 5 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section).

Page 43configuration_pollutants1

em rate em rate_units guarantee_level

_explain

req_monitoring

eq_recordkeeping

req_reporting Cherokee Unit 2 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 Performance Test Cherokee Unit 3 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). The actual 30-day

NOx limit for Cherokee Unit 3 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu. Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPAD130 0.88 lb/m mbtu SO2 limit from Nov 1 to Mar 1. Unit 4 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of VERP(See Note section). Units 1&4 combined must meet an annual % removal of 20%. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 The actual 30-day

NOx limit for Cherokee Unit 4 is 0.40 lb/mmbtu. The data entry screen cuts it to 0.4 lb/mmbtu. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPPB133 Comanche Units 1 & 2 share the 0.10 lb/mmbtu annual limit. The emissions from the units combined shall not exceed 0.10 lb/mmbtu on an annual rolling average. Note that the limit is 0.10, the data entryscreen only allowed 0.1 to be entered. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPPB133 The 30-day

lim it is 0.20 but the data entry only allowed for 0.2. The annual limit is 0.40 but data entry only allowed 0.4. Units 1 & 2 share the 0.15 lb/mmbtu annual limit. Combined shall not exceed 0.15 lb/mmbtu on an annual rolling average. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPPB133 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPPB133 The 30-day

lim it is 0.20 but the data entry only allowed for 0.2. Units 1 & 2 share the 0.15 lb/mmbtu annual limit. Combined shall not exceed 0.15 lb/mmbtu on an annual rolling average. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPPB133 Comanche Units 1 & 2 share the 0.10 lb/mmbtu annual limit. The emissions from the units combined shall not exceed 0.10 lb/mmbtu on an annual rolling average. Note that the limit is 0.10, the data entryscreen only allowed 0.1 to be entered. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPPB133 0.012 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 Compliance based on annual stack testing. No Stack Test Test Report Colorado Construction Permit #04PB1015 Performance Test No Stack Test Test Report Colorado Construction Permit #04PB1015 0.019 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 0.12 pound per million British Thermal Unit (lb/MMBtu)

No CEMS Quarterly excess emissions and monitor downtime report. Colorado Construction Permit #04PB1015 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPDE136 Arapahoe Unit 4 is required to meet an annual 20% SO2 removal requirement.Arapahoe Unit 4 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPDE136 The actual 30-day

NOx limit for Arapahoe Unit 4 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu.Arapahoe Units 3 & 4 have an averaging plan for the Part 76 annual NOx rate limit. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPDE136 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPAD130 0.88 lb/m mbtu SO2 limit from Nov 1 to Mar 1. Unit 1 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of VERP(See Note section). Units 1&4 combined must meet an annual % removal of 20%. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 The actual 30-day

NOx limit for Cherokee Unit 1 is 0.60 lb/mmbtu. The data entry screen cuts it to 0.6 lb/mmbtu.Cherokee Units 1 & 2 have an averaging plan for the Part 76 annual NOx rate limit. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPAD130 Arapahoe Units 3 & 4 have an averaging plan for the Part 76 annual NOx rate limit. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPDE136 Cherokee Units 1 & 2 have an averaging plan for the Part 76 annual NOx rate limit. CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPAD130 0.08 pound per million British Thermal Unit (lb/MMBtu)

No CEMS Quarterly excess emissions and monitor downtime report. Colorado Construction Permit #04PB1015 0.07 pound per million British Thermal Unit (lb/MMBtu)

No CEMS Quarterly excess emissions and monitor downtime report. Colorado Construction Permit #04PB1015 The Hg limit is a 12-month rolling average. No Stack Testing will be combined with measured flow to calculate hourly Hg mass emissions. Once CEM can be fully certified, compliance will be done with CEM. Quarterly

excess emissions and monitor downtime report. Colorado Construction Permit #04PB1015 0.003 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 0.00064 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 0.00049 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 0.0042 pound per million British Thermal Unit (lb/MMBtu)

No Stack Test Test Report Colorado Construction Permit #04PB1015 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPRO132 CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPRO132 The 30-day

lim it is 0.160 lb/mmbtu and the data entry screen only

allowed 0.16. The 90-day lim it is 0.130 lb/mmbtu and the data entry screen only

allowed 0.13. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPRO132 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPDE136 Arapahoe Unit 3 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). CEMS Quarterly

excess emissions and monitor downtime report. Title V compliance reports. Colorado Operating Permit #96OPDE136 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPRO132 The 3-hour limit is 0.70 lb/mmbtu and the data entry screen only

allowed 0.7. The 90-day lim it is 0.40 lb/mmbtu and the data entry screen only

allowed 0.4. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPRO132 The 30-day

lim it is 0.160 lb/mmbtu and the data entry screen only

allowed 0.16. The 90-day lim it is 0.130 lb/mmbtu and the data entry screen only

allowed 0.13. CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPRO132 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPMR129 CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPMR129 CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPMR129 Performance Test Stack testing is required every five years if test results are <50% of limit, every three years of test results are >50% but less than 75% of limit, and every year if test results are >75% of limit. Test Reports

Colorado Operating Permit #96OPBO131 The annual limit is 0.40 but data entry only allowed 0.4. CEMS Quarterly excess emissions and monitor downtime report. Colorado Operating Permit #96OPBO131 Valm ont Unit 5 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section). CEMS Quarterly

excess emissions and monitor downtime report. Colorado Operating Permit #96OPBO131

Page 44configuration_pollutants1

Colorado Operating Permit #96OPAD130

Cherokee Unit 3 is required to meet an annual tonnage limit of 10,500 tons or 70% removal as part of the Voluntary Em issions Reduction Program (See Note section).

Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPPB133 Colorado Operating Permit #96OPPB133 Colorado Operating Permit #96OPPB133 Colorado Operating Permit #96OPPB133 Colorado Operating Permit #96OPPB133 Colorado Operating Permit #96OPPB133 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPAD130 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPAD130 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Construction Permit #04PB1015 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPDE136 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPRO132 Colorado Operating Permit #96OPMR129 Colorado Operating Permit #96OPMR129 Colorado Operating Permit #96OPMR129 Colorado Operating Permit #96OPBO131 Colorado Operating Permit #96OPBO131 Colorado Operating Permit #96OPBO131

Page 45control_technologies

facility _id configuration_id

component_id

control_id project_titleproject_type vendor_name

vndor_contact

vendor_phone 470 Unit 1 ACI1 1 Comanche Hg Controls Project Non-Demonstration

ADA Evironm ental Solutions

John Barr 3037341727 470 Unit 2 ACI2 2 Comanche Hg Controls Project Non-Demonstration

ADA Evironm ental Solutions

John Barr 3037341727 470 Unit 3 ACI3 3 Comanche Hg Controls Project Non-Demonstration

ADA Evironm ental Solutions

John Barr 3037341727

Page 46control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive 8100 Southpark W ay, Unit B

Littleton CO 80120 3/31/2010 Brominaded Activated Carbon 8100 Southpark W ay, Unit B

Littleton CO 80120 3/31/2010 Brominaded Activated Carbon 8100 Southpark W ay, Unit B

Littleton CO 80120 3/31/2010 Brominaded Activated Carbon

Page 47control_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 Ductwork upstream of the SO2 and PM controls Ductwork upstream of the SO2 and PM controls Ductwork downstream of the NOx controls and upstream of the SO2 and PM controls 1.47E-05 lb/MW h

Page 48control_technologies

feed_rate_units

Page 49control_coal_ranks

facility _id configuration_id

component_id

control_id coal_type 470 Unit 1 ACI1 1 subbituminous 470 Unit 2 ACI2 2 subbituminous 470 Unit 3 ACI3 3 subbituminous

Page 50control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e 470 Unit 1 ACI1 1 Total Mercury (Hgt) 470 Unit 2 ACI2 2 Total Mercury (Hgt) 470 Unit 3 ACI3 3 Total Mercury (Hgt)

Page 51control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year 470 Unit 1 ACI1 1 Yes No 2343085 690244 470 Unit 2 ACI2 2 Yes No 2343085 690244 470 Unit 3 ACI3 3 No Yes 4195544 3167002

Page 52control_costs

CBI FALSE FALSE FALSE

Page 53misc_controls

facility _id misc_control_id

control_description

Page 54misc_control_configurations

facility _id misc_control_id

configuration_id

Page 55fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_type state_country other_country

county 465 BTMDNA001 1/1/2009 8882.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA002 1/1/2009 8844.3 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0032/1/2009 10372.4 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0043/1/2009 10403.8 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0053/1/2009 10356.2 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0063/1/2009 10242 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0073/1/2009 10582.4 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0084/1/2009 10335.8 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0094/1/2009 10257.8 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0105/1/2009 10324.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA011 5/1/2009 10328.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0126/1/2009 10769.8 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0136/1/2009 10250 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0146/1/2009 10240.2 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0156/1/2009 10327 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0167/1/2009 10336.2 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0177/1/2009 10392 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0187/1/2009 10672.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0197/1/2009 10148.2 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0208/1/2009 10315.7 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA021 8/1/2009 10296.3 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0228/1/2009 10357.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0239/1/2009 10333.6 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0249/1/2009 10292.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA0259/1/2009 10283.4 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA026

10/1/2009 10138 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA027

11/1/2009 10326.1 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA028

11/1/2009 10354.2 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA029

11/1/2009 10402 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA030

12/1/2009 10523.4 short tons (2000 lbs) coal WY WY - Campbell 465 BTMDNA031

2/1/2009 10177.9 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA001

5/1/2009 10263.8 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA002

5/1/2009 10254.1 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA003

8/1/2009 10252.8 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA004

9/1/2009 9658.8 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA005

9/1/2009 10258.7 short tons (2000 lbs) coal WY WY - Campbell 465 WT MDNA006

10/1/2009 9693.9 short tons (2000 lbs) coal WY WY - Campbell 469 BOWAUG 8/1/2009 11368 short tons (2000 lbs) coal CO CO - Delta 469 BOW DEC 12/1/2009 9926.8 short tons (2000 lbs) coal CO CO - Delta 469 BOWJUL 7/1/2009 11377 short tons (2000 lbs) coal CO CO - Delta 469 BOW MAR 3/1/2009 11174.4 short tons (2000 lbs) coal CO CO - Delta 469 BOW NOV 11/1/2009 11218.2 short tons (2000 lbs) coal CO CO - Delta 469 BOW SEP 9/1/2009 11397 short tons (2000 lbs) coal CO CO - Delta 469 COW OAPR 4/1/2009 10905.6 short tons (2000 lbs) coal CO CO - Moffat 469 COW OFEB 2/1/2009 33030.9 short tons (2000 lbs) coal CO CO - Moffat 469 COW OJAN 1/1/2009 10514 short tons (2000 lbs) coal CO CO - Moffat 469 COW OMAR 3/1/2009 32746.4 short tons (2000 lbs) coal CO CO - Moffat 469 FCAPR 4/1/2009 107121.5 short tons (2000 lbs) coal CO CO - Routt 469 FCAUG 8/1/2009 144972.2 short tons (2000 lbs) coal CO CO - Routt 469 FCDEC 12/1/2009 83879.5 short tons (2000 lbs) coal CO CO - Routt 469 FCFEB 2/1/2009 108860.2 short tons (2000 lbs) coal CO CO - Routt

Page 56fuel_shipments

469 FCJAN 1/1/2009 105558.3 short tons (2000 lbs) coal CO CO - Routt 469 FCJUL 7/1/2009 121754.5 short tons (2000 lbs) coal CO CO - Routt 469 FCJUN 6/1/2009 48657.5 short tons (2000 lbs) coal CO CO - Routt 469 FCMAR 3/1/2009 131530.1 short tons (2000 lbs) coal CO CO - Routt 469 FCMAY 5/1/2009 144545.7 short tons (2000 lbs) coal CO CO - Routt 469 FCNOV 11/1/2009 132932 short tons (2000 lbs) coal CO CO - Routt 469 FCOCT 10/1/2009 154557.8 short tons (2000 lbs) coal CO CO - Routt 469 FCSEP 9/1/2009 121537.1 short tons (2000 lbs) coal CO CO - Routt 469 OBAPR 4/1/2009 33550 short tons (2000 lbs) coal CO CO - Gunnison 469 OBAUG 8/1/2009 34081.7 short tons (2000 lbs) coal CO CO - Gunnison 469 OBFEB 2/1/2009 22132.9 short tons (2000 lbs) coal CO CO - Gunnison 469 OBJAN 1/1/2009 10984.3 short tons (2000 lbs) coal CO CO - Gunnison 469 OBJUL 7/1/2009 22536.9 short tons (2000 lbs) coal CO CO - Gunnison 469 OBJUN 6/1/2009 11136.7 short tons (2000 lbs) coal CO CO - Gunnison 469 OBMAR 3/1/2009 33212.7 short tons (2000 lbs) coal CO CO - Gunnison 469 OBMAY 5/1/2009 10987.1 short tons (2000 lbs) coal CO CO - Gunnison 469 OBSEP 9/1/2009 33851.5 short tons (2000 lbs) coal CO CO - Gunnison 469 WEAPR 4/1/2009 32822.9 short tons (2000 lbs) coal CO CO - Delta 469 WEAUG 8/1/2009 21938.1 short tons (2000 lbs) coal CO CO - Delta 469 WEJUL 7/1/2009 44029.9 short tons (2000 lbs) coal CO CO - Delta 469 WEJUN 6/1/2009 21991.8 short tons (2000 lbs) coal CO CO - Delta 469 WE MAY 5/1/2009 21466.7 short tons (2000 lbs) coal CO CO - Delta 469 WE NOV 11/1/2009 10988.4 short tons (2000 lbs) coal CO CO - Delta 469 WEOCT 10/1/2009 32841 short tons (2000 lbs) coal CO CO - Delta 469 WESEP 9/1/2009 21950.4 short tons (2000 lbs) coal CO CO - Delta 470 ANAPR 4/1/2009 32456.4 short tons (2000 lbs) coal WY WY - Campbell 470 ANAPR3 4/1/2009 10922.3 short tons (2000 lbs) coal WY WY - Campbell 470 ANMAR 3/1/2009 75636.7 short tons (2000 lbs) coal WY WY - Campbell 470 ANMAR3 3/1/2009 32456.5 short tons (2000 lbs) coal WY WY - Campbell 470 ANOCT 10/1/2009 64478.2 short tons (2000 lbs) coal WY WY - Campbell 470 ANSEP 9/1/2009 54153.3 short tons (2000 lbs) coal WY WY - Campbell 470 BAAPR 4/1/2009 113283 short tons (2000 lbs) coal WY WY - Campbell 470 BAAPR3 4/1/2009 20527.3 short tons (2000 lbs) coal WY WY - Campbell 470 BAAUG 8/1/2009 133828.5 short tons (2000 lbs) coal WY WY - Campbell 470 BAAUG3 8/1/2009 40885.3 short tons (2000 lbs) coal WY WY - Campbell 470 BADEC 12/1/2009 201918 short tons (2000 lbs) coal WY WY - Campbell 470 BADEC3 12/1/2009 81772.4 short tons (2000 lbs) coal WY WY - Campbell 470 BAFEB 2/1/2009 184813.6 short tons (2000 lbs) coal WY WY - Campbell 470 BAJAN 1/1/2009 243198.2 short tons (2000 lbs) coal WY WY - Campbell 470 BAJUL 7/1/2009 144303 short tons (2000 lbs) coal WY WY - Campbell 470 BAJUL3 7/1/2009 41236.3 short tons (2000 lbs) coal WY WY - Campbell 470 BAJUN 6/1/2009 144721.8 short tons (2000 lbs) coal WY WY - Campbell 470 BAJUN3 6/1/2009 40788.2 short tons (2000 lbs) coal WY WY - Campbell 470 BAMAR 3/1/2009 123593.9 short tons (2000 lbs) coal WY WY - Campbell 470 BAMAY 5/1/2009 196524.1 short tons (2000 lbs) coal WY WY - Campbell 470 BAMAY3 5/1/2009 31016.6 short tons (2000 lbs) coal WY WY - Campbell 470 BANOV 11/1/2009 114727.7 short tons (2000 lbs) coal WY WY - Campbell 470 BAOCT 10/1/2009 123960.9 short tons (2000 lbs) coal WY WY - Campbell 470 BAOCT3 10/1/2009 72458.7 short tons (2000 lbs) coal WY WY - Campbell 470 BASEP 9/1/2009 91640.4 short tons (2000 lbs) coal WY WY - Campbell 470 BASEP3 9/1/2009 40007.6 short tons (2000 lbs) coal WY WY - Campbell 477 BTAPR 4/1/2009 45248.11 short tons (2000 lbs) coal WY WY - Campbell

Page 57fuel_shipments

477 BTJAN 1/1/2009 35757.65 short tons (2000 lbs) coal WY WY - Campbell 477 BTJUN 6/1/2009 9098.09 short tons (2000 lbs) coal WY WY - Campbell 477 BTMAY 5/1/2009 53906.27 short tons (2000 lbs) coal WY WY - Campbell 477 ECAUG 8/1/2009 11355.42 short tons (2000 lbs) coal CO CO - Gunnison 477 ECJUL 7/1/2009 33850.06 short tons (2000 lbs) coal CO CO - Gunnison 477 ECJUN 6/1/2009 11170.26 short tons (2000 lbs) coal CO CO - Gunnison 477 ECSEP 9/1/2009 22689.67 short tons (2000 lbs) coal CO CO - Gunnison 477 FCAUG 8/1/2009 44127.57 short tons (2000 lbs) coal CO CO - Routt 477 FCDEC 12/1/2009 31389.04 short tons (2000 lbs) coal CO CO - Routt 477 FCJUL 7/1/2009 22206.09 short tons (2000 lbs) coal CO CO - Routt 477 FCJUN 6/1/2009 10948 short tons (2000 lbs) coal CO CO - Routt 477 FCSEP 9/1/2009 22139.21 short tons (2000 lbs) coal CO CO - Routt 477 SPNOV 11/1/2009 44280.23 short tons (2000 lbs) coal MT MT - Musselshell 477 SPOCT 10/1/2009 40220.2 short tons (2000 lbs) coal MT MT - Musselshell 477 WEAUG 8/1/2009 10985.49 short tons (2000 lbs) coal CO CO - Delta 477 WE DEC 12/1/2009 10772.33 short tons (2000 lbs) coal CO CO - Delta 477 WESEP 9/1/2009 10970.59 short tons (2000 lbs) coal CO CO - Delta 525 TMAPR 4/1/2009 106970.8 short tons (2000 lbs) coal CO CO - Routt 525 TMAUG 8/1/2009 124519.2 short tons (2000 lbs) coal CO CO - Routt 525 TMDEC 12/1/2009 80082.4 short tons (2000 lbs) coal CO CO - Routt 525 TMFEB 2/1/2009 125692.8 short tons (2000 lbs) coal CO CO - Routt 525 TMJAN 1/1/2009 125792.4 short tons (2000 lbs) coal CO CO - Routt 525 TMJUL 7/1/2009 129538.9 short tons (2000 lbs) coal CO CO - Routt 525 TMJUN 6/1/2009 67460 short tons (2000 lbs) coal CO CO - Routt 525 TMMAR 3/1/2009 126298.8 short tons (2000 lbs) coal CO CO - Routt 525 TMMAY 5/1/2009 99238.2 short tons (2000 lbs) coal CO CO - Routt 525 TMNOV 11/1/2009 98685.3 short tons (2000 lbs) coal CO CO - Routt 525 TMOCT 10/1/2009 116748.4 short tons (2000 lbs) coal CO CO - Routt 525 TMSEP 9/1/2009 125862.7 short tons (2000 lbs) coal CO CO - Routt 6248 BAMAY 5/1/2009 9933.3 short tons (2000 lbs) coal WY WY - Campbell 6248 CCFEB 2/1/2009 89852.5 short tons (2000 lbs) coal WY WY - Campbell 6248 EBAUG 8/1/2009 79514.3 short tons (2000 lbs) coal WY WY - Campbell 6248 EBDEC 12/1/2009 107319.9 short tons (2000 lbs) coal WY WY - Campbell 6248 EBFEB 2/1/2009 9713.4 short tons (2000 lbs) coal WY WY - Campbell 6248 EBJAN 1/1/2009 120383 short tons (2000 lbs) coal WY WY - Campbell 6248 EBJUL 7/1/2009 29782.1 short tons (2000 lbs) coal WY WY - Campbell 6248 EBJUN 6/1/2009 60451.5 short tons (2000 lbs) coal WY WY - Campbell 6248 EBMAR 3/1/2009 19983.5 short tons (2000 lbs) coal WY WY - Campbell 6248 EBMAY 5/1/2009 39799.4 short tons (2000 lbs) coal WY WY - Campbell 6248 EBNOV 11/1/2009 152072.3 short tons (2000 lbs) coal WY WY - Campbell 6248 EBOCT 10/1/2009 121100.8 short tons (2000 lbs) coal WY WY - Campbell 6248 EBSEP 9/1/2009 30458.9 short tons (2000 lbs) coal WY WY - Campbell

Page 58fuel_shipments

coal_seam shipment_method Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train B Unit Train B Unit Train B Unit Train B Unit Train B Unit Train B Unit Train CO - Moffat Unit Train CO - Moffat Unit Train CO - Moffat Unit Train CO - Moffat Unit Train

Wadge Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train

Page 59fuel_shipments

Wadge Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train Wedge Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train D Unit Train D Unit Train D Unit Train D Unit Train D Unit Train D Unit Train D Unit Train D Unit Train D Unit Train B and E Unit Train B and E Unit Train B and E Unit Train B and E Unit Train B and E Unit Train B and E Unit Train B and E Unit Train B and E Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train

Page 60fuel_shipments

Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train D Unit Train D Unit Train D Unit Train D Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train Wadge Unit Train 4, 5, 6 & 7 Unit Train 4, 5, 6 & 7 Unit Train B and E Unit Train B and E Unit Train B and E Unit Train Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wadge Trucks Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train Wyodak Unit Train

Page 61fuel_shipment_configurations

facility _id shipment_id

configuration_id 465 BTMDNA001

Unit 3 465 BTMDNA001

Unit 4 465 BTMDNA002

Unit 3 465 BTMDNA002

Unit 4 465 BTMDNA003

Unit 3 465 BTMDNA003

Unit 4 465 BTMDNA004

Unit 3 465 BTMDNA004

Unit 4 465 BTMDNA005

Unit 3 465 BTMDNA005

Unit 4 465 BTMDNA006

Unit 3 465 BTMDNA006

Unit 4 465 BTMDNA007

Unit 3 465 BTMDNA007

Unit 4 465 BTMDNA008

Unit 3 465 BTMDNA008

Unit 4 465 BTMDNA009

Unit 3 465 BTMDNA009

Unit 4 465 BTMDNA010

Unit 3 465 BTMDNA010

Unit 4 465 BTMDNA011

Unit 3 465 BTMDNA011

Unit 4 465 BTMDNA012

Unit 3 465 BTMDNA012

Unit 4 465 BTMDNA013

Unit 3 465 BTMDNA013

Unit 4 465 BTMDNA014

Unit 3 465 BTMDNA014

Unit 4 465 BTMDNA015

Unit 3 465 BTMDNA015

Unit 4 465 BTMDNA016

Unit 3 465 BTMDNA016

Unit 4 465 BTMDNA017

Unit 3 465 BTMDNA017

Unit 4 465 BTMDNA018

Unit 3 465 BTMDNA018

Unit 4 465 BTMDNA019

Unit 3 465 BTMDNA019

Unit 4 465 BTMDNA020

Unit 3 465 BTMDNA020

Unit 4 465 BTMDNA021

Unit 3 465 BTMDNA021

Unit 4 465 BTMDNA022

Unit 3 465 BTMDNA022

Unit 4 465 BTMDNA023

Unit 3 465 BTMDNA023

Unit 4 465 BTMDNA024

Unit 3 465 BTMDNA024

Unit 4 465 BTMDNA025

Unit 3 465 BTMDNA025

Unit 4 465 BTMDNA026

Unit 3

Page 62fuel_shipment_configurations

465 BTMDNA026

Unit 4 465 BTMDNA027

Unit 3 465 BTMDNA027

Unit 4 465 BTMDNA028

Unit 3 465 BTMDNA028

Unit 4 465 BTMDNA029

Unit 3 465 BTMDNA029

Unit 4 465 BTMDNA030

Unit 3 465 BTMDNA030

Unit 4 465 BTMDNA031

Unit 3 465 BTMDNA031

Unit 4 465 WT MDNA001

Unit 3 465 WT MDNA001

Unit 4 465 WT MDNA002

Unit 3 465 WT MDNA002

Unit 4 465 WT MDNA003

Unit 3 465 WT MDNA003

Unit 4 465 WT MDNA004

Unit 3 465 WT MDNA004

Unit 4 465 WT MDNA005

Unit 3 465 WT MDNA005

Unit 4 465 WT MDNA006

Unit 3 465 WT MDNA006

Unit 4 469 BOWAUG Unit 1 469 BOWAUG Unit 2 469 BOWAUG Unit 3 469 BOWAUG Unit 4 469 BOW DEC Unit 1 469 BOW DEC Unit 2 469 BOW DEC Unit 3 469 BOW DEC Unit 4 469 BOWJUL Unit 1 469 BOWJUL Unit 2 469 BOWJUL Unit 3 469 BOWJUL Unit 4 469 BOW MAR Unit 1 469 BOW MAR Unit 2 469 BOW MAR Unit 3 469 BOW MAR Unit 4 469 BOW NOV Unit 1 469 BOW NOV Unit 2 469 BOW NOV Unit 3 469 BOW NOV Unit 4 469 BOW SEP Unit 1 469 BOW SEP Unit 2 469 BOW SEP Unit 3 469 BOW SEP Unit 4 469 COW OAPR

Unit 1 469 COW OAPR

Unit 2 469 COW OAPR

Unit 3 469 COW OAPR

Unit 4 469 COW OFEB

Unit 1

Page 63fuel_shipment_configurations

469 COW OFEB

Unit 2 469 COW OFEB

Unit 3 469 COW OFEB

Unit 4 469 COW OJANUnit 1 469 COW OJANUnit 2 469 COW OJANUnit 3 469 COW OJANUnit 4 469 COW OMAR

Unit 1 469 COW OMAR

Unit 2 469 COW OMAR

Unit 3 469 COW OMAR

Unit 4 469 FCAPR Unit 1 469 FCAPR Unit 2 469 FCAPR Unit 3 469 FCAPR Unit 4 469 FCAUG Unit 1 469 FCAUG Unit 2 469 FCAUG Unit 3 469 FCAUG Unit 4 469 FCDEC Unit 1 469 FCDEC Unit 2 469 FCDEC Unit 3 469 FCDEC Unit 4 469 FCFEB Unit 1 469 FCFEB Unit 2 469 FCFEB Unit 3 469 FCFEB Unit 4 469 FCJAN Unit 1 469 FCJAN Unit 2 469 FCJAN Unit 3 469 FCJAN Unit 4 469 FCJUL Unit 1 469 FCJUL Unit 2 469 FCJUL Unit 3 469 FCJUL Unit 4 469 FCJUN Unit 1 469 FCJUN Unit 2 469 FCJUN Unit 3 469 FCJUN Unit 4 469 FCMAR Unit 1 469 FCMAR Unit 2 469 FCMAR Unit 3 469 FCMAR Unit 4 469 FCMAY Unit 1 469 FCMAY Unit 2 469 FCMAY Unit 3 469 FCMAY Unit 4 469 FCNOV Unit 1 469 FCNOV Unit 2 469 FCNOV Unit 3 469 FCNOV Unit 4 469 FCOCT Unit 1

Page 64fuel_shipment_configurations

469 FCOCT Unit 2 469 FCOCT Unit 3 469 FCOCT Unit 4 469 FCSEP Unit 1 469 FCSEP Unit 2 469 FCSEP Unit 3 469 FCSEP Unit 4 469 OBAPR Unit 1 469 OBAPR Unit 2 469 OBAPR Unit 3 469 OBAPR Unit 4 469 OBAUG Unit 1 469 OBAUG Unit 2 469 OBAUG Unit 3 469 OBAUG Unit 4 469 OBFEB Unit 1 469 OBFEB Unit 2 469 OBFEB Unit 3 469 OBFEB Unit 4 469 OBJAN Unit 1 469 OBJAN Unit 2 469 OBJAN Unit 3 469 OBJAN Unit 4 469 OBJUL Unit 1 469 OBJUL Unit 2 469 OBJUL Unit 3 469 OBJUL Unit 4 469 OBJUN Unit 1 469 OBJUN Unit 2 469 OBJUN Unit 3 469 OBJUN Unit 4 469 OBMAR Unit 1 469 OBMAR Unit 2 469 OBMAR Unit 3 469 OBMAR Unit 4 469 OBMAY Unit 1 469 OBMAY Unit 2 469 OBMAY Unit 3 469 OBMAY Unit 4 469 OBSEP Unit 1 469 OBSEP Unit 2 469 OBSEP Unit 3 469 OBSEP Unit 4 469 WEAPR Unit 1 469 WEAPR Unit 2 469 WEAPR Unit 3 469 WEAPR Unit 4 469 WEAUG Unit 1 469 WEAUG Unit 2 469 WEAUG Unit 3 469 WEAUG Unit 4 469 WEJUL Unit 1

Page 65fuel_shipment_configurations

469 WEJUL Unit 2 469 WEJUL Unit 3 469 WEJUL Unit 4 469 WEJUN Unit 1 469 WEJUN Unit 2 469 WEJUN Unit 3 469 WEJUN Unit 4 469 WE MAY Unit 1 469 WE MAY Unit 2 469 WE MAY Unit 3 469 WE MAY Unit 4 469 WE NOV Unit 1 469 WE NOV Unit 2 469 WE NOV Unit 3 469 WE NOV Unit 4 469 WEOCT Unit 1 469 WEOCT Unit 2 469 WEOCT Unit 3 469 WEOCT Unit 4 469 WESEP Unit 1 469 WESEP Unit 2 469 WESEP Unit 3 469 WESEP Unit 4 470 ANAPR Unit 1 470 ANAPR Unit 2 470 ANAPR3 Unit 3 470 ANMAR Unit 1 470 ANMAR Unit 2 470 ANMAR3 Unit 3 470 ANOCT Unit 1 470 ANOCT Unit 2 470 ANSEP Unit 1 470 ANSEP Unit 2 470 BAAPR Unit 1 470 BAAPR Unit 2 470 BAAPR3 Unit 3 470 BAAUG Unit 1 470 BAAUG Unit 2 470 BAAUG3 Unit 3 470 BADEC Unit 1 470 BADEC Unit 2 470 BADEC3 Unit 3 470 BAFEB Unit 1 470 BAFEB Unit 2 470 BAJAN Unit 1 470 BAJAN Unit 2 470 BAJUL Unit 1 470 BAJUL Unit 2 470 BAJUL3 Unit 3 470 BAJUN Unit 1 470 BAJUN Unit 2 470 BAJUN3 Unit 3

Page 66fuel_shipment_configurations

470 BAMAR Unit 1 470 BAMAR Unit 2 470 BAMAY Unit 1 470 BAMAY Unit 2 470 BAMAY3 Unit 3 470 BANOV Unit 1 470 BANOV Unit 2 470 BAOCT Unit 1 470 BAOCT Unit 2 470 BAOCT3 Unit 3 470 BASEP Unit 1 470 BASEP Unit 2 470 BASEP3 Unit 3 477 BTAPR Unit 5 477 BTJAN Unit 5 477 BTJUN Unit 5 477 BTMAY Unit 5 477 ECAUG Unit 5 477 ECJUL Unit 5 477 ECJUN Unit 5 477 ECSEP Unit 5 477 FCAUG Unit 5 477 FCDEC Unit 5 477 FCJUL Unit 5 477 FCJUN Unit 5 477 FCSEP Unit 5 477 SPNOV Unit 5 477 SPOCT Unit 5 477 WEAUG Unit 5 477 WE DEC Unit 5 477 WESEP Unit 5 525 TMAPR Unit 1 525 TMAPR Unit 2 525 TMAUG Unit 1 525 TMAUG Unit 2 525 TMDEC Unit 1 525 TMDEC Unit 2 525 TMFEB Unit 1 525 TMFEB Unit 2 525 TMJAN Unit 1 525 TMJAN Unit 2 525 TMJUL Unit 1 525 TMJUL Unit 2 525 TMJUN Unit 1 525 TMJUN Unit 2 525 TMMAR Unit 1 525 TMMAR Unit 2 525 TMMAY Unit 1 525 TMMAY Unit 2 525 TMNOV Unit 1 525 TMNOV Unit 2 525 TMOCT Unit 1

Page 67fuel_shipment_configurations

525 TMOCT Unit 2 525 TMSEP Unit 1 525 TMSEP Unit 2 6248 BAMAY Unit 1 6248 CCFEB Unit 1 6248 EBAUG Unit 1 6248 EBDEC Unit 1 6248 EBFEB Unit 1 6248 EBJAN Unit 1 6248 EBJUL Unit 1 6248 EBJUN Unit 1 6248 EBMAR Unit 1 6248 EBMAY Unit 1 6248 EBNOV Unit 1 6248 EBOCT Unit 1 6248 EBSEP Unit 1

Page 68fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units 465 BTMDNA001

013 8882.1 tons 0.25 4.93 8879 Btu/lb 465 BTMDNA002

020 8844.3 tons 0.38 5.13 8871 Btu/lb 465 BTMDNA003

014 10372.4 tons 0.22 4.27 8955 Btu/lb 465 BTMDNA004

021 10403.8 tons 0.26 5.21 8921 Btu/lb 465 BTMDNA005

022 10356.2 tons 0.31 5.25 8905 Btu/lb 465 BTMDNA006

023 10242 tons 0.23 4.88 8853 Btu/lb 465 BTMDNA007

024 10582.4 tons 0.23 5.07 8885 Btu/lb 465 BTMDNA008

015 10335.8 tons 0.25 4.73 8935 Btu/lb 465 BTMDNA009

016 10257.8 tons 0.21 4.27 8917 Btu/lb 465 BTMDNA010

017 10324.1 tons 0.31 5.6 8885 Btu/lb 465 BTMDNA011

018 10328.1 tons 0.33 5.21 8909 Btu/lb 465 BTMDNA012

002 10769.8 tons 0.25 5.26 8823 Btu/lb 465 BTMDNA013

003 10250 tons 0.26 5.03 8800 Btu/lb 465 BTMDNA014

004 10240.2 tons 0.22 4.09 8953 Btu/lb 465 BTMDNA015

005 10327 tons 0.2 4.7 8917 Btu/lb 465 BTMDNA016

006 10336.2 tons 0.23 4.89 8822 Btu/lb 465 BTMDNA017

007 10392 tons 0.27 5 8902 Btu/lb 465 BTMDNA018

008 10672.1 tons 0.29 4.95 8861 Btu/lb 465 BTMDNA019

025 10148.2 tons 0.2 4.32 8860 Btu/lb 465 BTMDNA020

009 10315.7 tons 0.23 5.99 8770 Btu/lb 465 BTMDNA021

010 10296.3 tons 0.24 4.73 8942 Btu/lb 465 BTMDNA022

011 10357.1 tons 0.33 5.07 8936 Btu/lb 465 BTMDNA023

012 10333.6 tons 0.29 5.3 8933 Btu/lb 465 BTMDNA024

027 10292.1 tons 0.25 5.66 8907 Btu/lb 465 BTMDNA025

029 10283.4 tons 0.3 4.86 8864 Btu/lb 465 BTMDNA026

032 10138 tons 0.33 5.17 8915 Btu/lb 465 BTMDNA027

033 10326.1 tons 0.28 5.16 8886 Btu/lb 465 BTMDNA028

034 10354.2 tons 0.32 5.54 8858 Btu/lb 465 BTMDNA029

035 10402 tons 0.28 5.11 8869 Btu/lb 465 BTMDNA030

036 10523.4 tons 0.37 6.81 8778 Btu/lb 465 BTMDNA031

037 10177.9 tons 0.29 4.82 8909 Btu/lb 465 WT MDNA001

9 10263.8 tons 0.37 4.89 8945 Btu/lb 465 WT MDNA002

01 10254.1 tons 0.32 5.74 8779 Btu/lb 465 WT MDNA003

26 10252.8 tons 0.35 4.88 8904 Btu/lb 465 WT MDNA004

28 9658.8 tons 0.35 4.89 8850 Btu/lb 465 WT MDNA005

30 10258.7 tons 0.38 5.25 8887 Btu/lb 465 WT MDNA006

31 9693.9 tons 0.37 4.85 8882 Btu/lb 469 BOWAUG BOWAUG 11368 tons 0.55 10 12182 Btu/lb 469 BOW DEC BOW DEC 9926.8 tons 0.51 9.12 12035 Btu/lb 469 BOWJUL BOWJUL 11377 tons 0.5 9.96 12034 Btu/lb 469 BOW MAR BOW MAR 11174.4 tons 0.51 9.79 11174.4 Btu/lb 469 BOW NOV BOW NOV 11218.2 tons 0.47 11.07 11686 Btu/lb 469 BOW SEP BOW SEP 11397 tons 0.51 10.93 11968 Btu/lb 469 COW OAPR

COW OAPR 10905.6 tons 0.36 6.26 10125 Btu/lb 469 COW OFEB

COW OFEB 33030.9 tons 0.37 6.3 10316 Btu/lb 469 COW OJANCOW OJAN 10514 tons 0.36 6.7 9930 Btu/lb 469 COW OMAR

COW OMAR 32746.4 tons 0.38 5.65 10322 Btu/lb 469 FCAPR FCAPR 107121.5 tons 0.48 10 11292 Btu/lb 469 FCAUG FCAUG 144972.2 tons 0.49 10.21 11279 Btu/lb 469 FCDEC FCDEC 83879.5 tons 0.47 10.04 11196 Btu/lb 469 FCFEB FCFEB 108860.2 tons 0.5 10.2 11404 Btu/lb

Page 69fuel_shipment_samples

469 FCJAN FCJAN 105558.3 tons 0.51 10.31 11285 Btu/lb 469 FCJUL FCJUL 121754.5 tons 0.51 9.77 11350 Btu/lb 469 FCJUN FCJUN 48657.5 tons 0.5 9.96 11313 Btu/lb 469 FCMAR FCMAR 131530.1 tons 0.49 10.32 11277 Btu/lb 469 FCMAY FCMAY 144545.7 tons 0.47 9.96 11226 Btu/lb 469 FCNOV FCNOV 132932 tons 0.48 9.74 11308 Btu/lb 469 FCOCT FCOCT 154557.8 tons 0.47 10.07 11247 Btu/lb 469 FCSEP FCSEP 121537.1 tons 0.48 9.83 11278 Btu/lb 469 OBAPR OBAPR 33550 tons 0.48 11.51 11454 Btu/lb 469 OBAUG OBAUG 34081.7 tons 0.46 11.85 11584 Btu/lb 469 OBFEB OBFEB 22132.9 tons 0.48 10.05 11579 Btu/lb 469 OBJAN OBJAN 10984.3 tons 0.46 11.77 11588 Btu/lb 469 OBJUL OBJUL 22536.9 tons 0.49 10.09 11742 Btu/lb 469 OBJUN OBJUN 11136.7 tons 0.48 10.71 11608 Btu/lb 469 OBMAR OBMAR 33212.7 tons 0.47 7.97 11964 Btu/lb 469 OBMAY OBMAY 10987.1 tons 0.47 8.36 11663 Btu/lb 469 OBSEP OBSEP 33851.5 tons 0.51 8.38 12100 Btu/lb 469 WEAPR WEAPR 32822.9 tons 0.45 8.4 11461 Btu/lb 469 WEAUG WEAUG 21938.1 tons 0.47 8.02 11503 Btu/lb 469 WEJUL WEJUL 44029.9 tons 0.46 8.26 11510 Btu/lb 469 WEJUN WEJUN 21991.8 tons 0.45 7.97 11490 Btu/lb 469 WE MAY WE MAY 21466.7 tons 0.43 8.86 11189 Btu/lb 469 WE NOV WE NOV 10988.4 tons 0.48 8.01 11512 Btu/lb 469 WEOCT WEOCT 32841 tons 0.48 8.43 11426 Btu/lb 469 WESEP WESEP 21950.4 tons 0.45 7.83 11446 Btu/lb 470 ANAPR ANAPR 32456.4 tons 0.283 5.454 8833 Btu/lb 470 ANAPR3 ANAPR3 10922.3 tons 0.29 5.24 8910 Btu/lb 470 ANMAR ANMAR 75636.7 tons 0.249 5.233 8809 Btu/lb 470 ANMAR3 ANMAR3 32456.5 tons 0.183 5.333 8847 Btu/lb 470 ANOCT ANOCT 64478.2 tons 0.26 5.188 8847 Btu/lb 470 ANSEP ANSEP 54153.3 tons 0.288 5.219 8915 Btu/lb 470 BAAPR BAAPR 113283 tons 0.267 4.188 8567 Btu/lb 470 BAAPR3 BAAPR3 20527.3 tons 0.26 4.125 8565 Btu/lb 470 BAAUG BAAUG 133828.5 tons 0.262 4.62 8553 Btu/lb 470 BAAUG3 BAAUG3 40885.3 tons 0.263 4.747 8541 Btu/lb 470 BADEC BADEC 201918 tons 0.263 4.851 8552 Btu/lb 470 BADEC3 BADEC3 81772.4 tons 0.264 4.823 8620 Btu/lb 470 BAFEB BAFEB 184813.6 tons 0.261 4.77 8570 Btu/lb 470 BAJAN BAJAN 243198.2 tons 0.281 4.637 8563 Btu/lb 470 BAJUL BAJUL 144303 tons 0.252 4.424 8547 Btu/lb 470 BAJUL3 BAJUL3 41236.3 tons 0.255 4.518 8554 Btu/lb 470 BAJUN BAJUN 144721.8 tons 0.275 4.482 8586 Btu/lb 470 BAJUN3 BAJUN3 40788.2 tons 0.275 4.31 8594 Btu/lb 470 BAMAR BAMAR 123593.9 tons 0.286 4.329 8604 Btu/lb 470 BAMAY BAMAY 196524.1 tons 0.279 4.37 8622 Btu/lb 470 BAMAY3 BAMAY3 31016.6 tons 0.287 4.533 8579 Btu/lb 470 BANOV BANOV 114727.7 tons 0.267 4.546 8641 Btu/lb 470 BAOCT BAOCT 123960.9 tons 0.263 4.475 8636 Btu/lb 470 BAOCT3 BAOCT3 72458.7 tons 0.262 4.533 8630 Btu/lb 470 BASEP BASEP 91640.4 tons 0.266 4.508 8586 Btu/lb 470 BASEP3 BASEP3 40007.6 tons 0.283 4.594 8581 Btu/lb 477 BTAPR BTAPR 45248.11 tons 0.262 5.165 8836 Btu/lb

Page 70fuel_shipment_samples

477 BTJAN BTJAN 35757.65 tons 0.295 5.087 8880 Btu/lb 477 BTJUN BTJUN 9098.09 tons 0.3 4.97 8867 Btu/lb 477 BTMAY BTMAY 53906.27 tons 0.345 5.049 8859 Btu/lb 477 ECAUG ECAUG 11355.42 tons 0.46 10.81 11710 Btu/lb 477 ECJUL ECJUL 33850.06 tons 0.487 10.859 11652 Btu/lb 477 ECJUN ECJUN 11170.26 tons 0.49 11.85 11432 Btu/lb 477 ECSEP ECSEP 22689.67 tons 0.5 7.11 12303 Btu/lb 477 FCAUG FCAUG 44127.57 tons 0.485 10.274 11235 Btu/lb 477 FCDEC FCDEC 31389.04 tons 0.301 10.426 11146 Btu/lb 477 FCJUL FCJUL 22206.09 tons 0.52 10.546 11239 Btu/lb 477 FCJUN FCJUN 10948 tons 0.47 10.1 11117 Btu/lb 477 FCSEP FCSEP 22139.21 tons 0.485 9.756 11280 Btu/lb 477 SPNOV SPNOV 44280.23 tons 0.48 10.058 11263 Btu/lb 477 SPOCT SPOCT 40220.2 tons 0.432 6.317 9983 Btu/lb 477 WEAUG WEAUG 10985.49 tons 0.46 8.46 11448 Btu/lb 477 WE DEC WE DEC 10772.33 tons 0.42 4.04 12035 Btu/lb 477 WESEP WESEP 10970.59 tons 0.43 7.46 11567 Btu/lb 525 TMAPR TMAPR 106970.8 tons 0.483 10.617 11146 Btu/lb 525 TMAUG TMAUG 124519.2 tons 0.492 10.527 11217 Btu/lb 525 TMDEC TMDEC 80082.4 tons 0.469 10.436 11125 Btu/lb 525 TMFEB TMFEB 125692.8 tons 0.501 10.747 11249 Btu/lb 525 TMJAN TMJAN 125792.4 tons 0.507 10.505 11181 Btu/lb 525 TMJUL TMJUL 129538.9 tons 0.502 10.268 11270 Btu/lb 525 TMJUN TMJUN 67460 tons 0.486 10.431 11189 Btu/lb 525 TMMAR TMMAR 126298.8 tons 0.489 10.811 11198 Btu/lb 525 TMMAY TMMAY 99238.2 tons 0.467 10.449 11077 Btu/lb 525 TMNOV TMNOV 98685.3 tons 0.476 9.869 11228 Btu/lb 525 TMOCT TMOCT 116748.4 tons 0.47 10.373 11156 Btu/lb 525 TMSEP TMSEP 125862.7 tons 0.485 10.146 11193 Btu/lb 6248 BAMAY BAMAY 9933.3 tons 0.37 4.71 8409 Btu/lb 6248 CCFEB CCFEB 89852.5 tons 0.33 5.95 8335 Btu/lb 6248 EBAUG EBAUG 79514.3 tons 0.36 4.82 8358 Btu/lb 6248 EBDEC EBDEC 107319.9 tons 0.36 5.01 8388 Btu/lb 6248 EBFEB EBFEB 9713.4 tons 0.41 4.95 8381 Btu/lb 6248 EBJAN EBJAN 120383 tons 0.36 4.85 8401 Btu/lb 6248 EBJUL EBJUL 29782.1 tons 0.38 5 8425 Btu/lb 6248 EBJUN EBJUN 60451.5 tons 0.36 4.83 8369 Btu/lb 6248 EBMAR EBMAR 19983.5 tons 0.33 4.65 8424 Btu/lb 6248 EBMAY EBMAY 39799.4 tons 0.33 5.16 8355 Btu/lb 6248 EBNOV EBNOV 152072.3 tons 0.38 4.98 8413 Btu/lb 6248 EBOCT EBOCT 121100.8 tons 0.38 4.95 8403 Btu/lb 6248 EBSEP EBSEP 30458.9 tons 0.39 4.86 8431 Btu/lb

Page 71fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_type

supplier_name

supplier_address contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Bowie Resources, LLC

P.O. Box 5057 contractual obligations Fuel supplier Colowyo Mine Company - On site lab 5731 State Highway

13 contractual obligations Fuel supplier Colowyo Mine Company - On site lab 5731 State Highway

13 contractual obligations Fuel supplier Colowyo Mine Company

5731 State Highway

13 contractual obligations Fuel supplier Colowyo Mine Company - On site lab 5731 State Highway

13 contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street

Page 72fuel_shipment_samples

contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Saels, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Mineral

600 Grant Street contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Cloud Peak Energy

8051 East Maplewood Avenue, Bldg. 4 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300

Page 73fuel_shipment_samples

contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Oxbow Carbon and Minerals

600 Grant Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Global Coal Sales Group, LLC

5509 South Garrison St. contractual obligations Fuel supplier Global Coal Sales Group, LLC

5509 South Garrison St. contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Peabody Coal Sales, LLC 701 Market Street contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Arch Coal Sales

City Place One, Suite 300 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333 contractual obligations Fuel supplier Alpha Resources

391 Inverness Parkway, Suite 333

Page 74fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Arch Coal Sales 5669 State Highway

450P.O. Box 406 Wright WY 82732 No Ashland KY 41105 Standard Laboratories 5144 Highway

133 Som erset CO 81434 No Ashland KY 41105 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Ashland KY 41105 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No Ashland KY 41105 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No Ashland KY 41105 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Ashland KY 41105 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No Meeker CO 81641 Colowyo Mine Company - On site lab 5731 State Highway

13 Meeker CO 81641 No Meeker CO 81641 Colowyo Mine Company - On site lab 5731 State Highway

13 Meeker CO 81641 No Meeker CO 81641 Colowyo Mine Company - On site lab 5731 State Highway

13 Meeker CO 81641 No Meeker CO 81641 Colowyo Mine Company - On site lab 5731 State Highway

13 Meeker CO 81641 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc. - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No

Page 75fuel_shipment_samples

St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc. - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No 600 Grant Street

CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc. 5144 Highway

133 Som erset CO 81434 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80111 Standard Laboratories, Inc. P.O. Drawer 3008

Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab at Eagle Butte 10023 Highway

14/16 Gillette WY 82716 No St. Louis MO 63141 Standard Laboratories, Inc - On site lab Black Thunder Mine5669 State Highway 450P.O. Box 406 Wright WY 82732 No

Page 76fuel_shipment_samples

St. Louis MO 63141 Standard Laboratories, Inc - On site lab Black Thunder Mine5669 State Highway 450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Standard Laboratories, Inc - On site lab Black Thunder Mine5669 State Highway 450P.O. Box 406 Wright WY 82732 No St. Louis MO 63141 Standard Laboratories, Inc - On site lab Black Thunder Mine5669 State Highway 450P.O. Box 406 Wright WY 82732 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No Denver CO 80203 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North America, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No Littleton CO 80123 SGS North America, Inc Minerals Services100 Portal Drive

Roundup MT 59072 No Littleton CO 80123 SGS North America, Inc Minerals Services100 Portal Drive

Roundup MT 59072 No St. Louis MO 63141 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63141 Standard Laboratories, Inc 5144 Highway

133 Som erset CO 81434 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis CO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No St. Louis MO 63101-1826 SGS North American, Inc - On site lab

Twentymi le Coal Com pany 29515 RCR #27

Oak Creek CO 80467 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 Highway14/16

Gillette WY 82716 No St. Louis MO 63141 Standard Laboratories, Inc - On site lab 5669 State Highway

450P.O. Box 406 Wright WY 82732 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No Englewood CO 80202 SGS North America, Inc - On site lab 10023 highway

14/16 Gillette WY 82716 No

Page 77fuel_shipment_samples

analysis_copies

Page 78fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL 477 BTAPR BTAPR Antim ony (Sb) 0.11 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Arsenic (As) 0.7 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Barium(Ba) 374 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Beryllium(Be) 0.1 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Cadmium (Cd) 0.04 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Chloride (Cl) 6 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Chromium (Cr) 3 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Cobalt (Co) 1.3 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Copper (Cu) 10 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Fluoride (F) 51.3 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Lead (Pb) 1.6 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Manganese (Mn) 10 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Mercury (Hg) 0.077 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Molybdenum(Mo) 0.4 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Nickel (Ni) 2 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Selenium(Se) 0.7 parts per million (dry) (ppm) FALSE 477 BTAPR BTAPR Vanadium(V) 10 parts per million (dry) (ppm) FALSE

Page 79test_reports

facility _id report_id report_type other_type report_description report_begin_date

report_end_date

before_control

during_deviation 465 ARA4 Hg Sep05

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 9/7/2005 9/8/2005 No No 469 CHE1 Hg Dec08

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 12/5/2008 12/5/2008 No No 469 CHE2 Hg Aug05

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 8/30/2005 8/30/2005 No No 469 CHE2 Hg Nov09

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. ######## ######## No No 469 CHE2 Hg Oct08

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. ######## ######## No No 469 CHE3 Hg Feb09

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 2/10/2009 2/10/2009 No No 469 CHE3 Hg Jun07

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 6/5/2007 6/5/2007 No No 469 CHE3 Hg Oct08

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. ######## ######## No No 469 CHE4 Hg Aug05

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 8/31/2005 9/1/2005 No No 469 CHE4 Hg Oct08

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

######## ######## No No 469 CHE4 Hg Oct09

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

10/6/2009 10/7/2009 No No 470 COM1 Hg Apr07

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

4/26/2007 5/2/2007 No No 470 COM1 Hg Mar09

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

3/4/2009 3/9/2009 No No 470 COM1 Hg Oct07

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

10/2/2007 10/5/2007 No No 470 COM1 Hg Sep06

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

9/28/2006 10/3/2006 No No 470 COM2 Hg Apr09

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

4/6/2009 4/7/2009 No No 470 COM2 Hg Dec07

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

######## ######## No No 470 COM2 Hg Sep06

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

9/15/2006 10/5/2006 No No 477 VAL5 Hg Jan08

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 1/22/2008 1/22/2008 No No 477 VAL5 Hg Jul09

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 7/23/2009 7/23/2009 No No 525 HAY1 Hg Aug05

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 8/25/2005 8/26/2005 No No 525 HAY1 Hg Feb09

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 2/12/2009 2/12/2009 No No 525 HAY1 Hg Jan08

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 1/24/2008 1/24/2008 No No 525 HAY1 Hg Jul09

other State LME Certification The was a test done on the unit in order to certify the unit's qualification as a low mass emitter under the Colorado mercury rule. 7/20/2009 7/21/2009 No No 525 HAY1 Hg Jun07

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 6/19/2007 6/19/2007 No No 525 HAY1 Hg Sep07

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 9/25/2007 9/25/2007 No No 525 HAY2 Hg Dec09

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

######## ######## No No 525 HAY2 Hg Jun07

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 6/21/2007 6/21/2007 No No 525 HAY2 Hg Nov07

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 11/1/2007 11/1/2007 No No 6248 PAW 1 Hg Aug05

other Internal Assessment The unit was tested as part of an internal assessment of Hg emissions from our units. There are no Hg emissions data to report from a CEMS, only Hg emissions info from the identified testing. 8/23/2005 8/23/2005 No No 6248 PAW 1 Hg Jul08

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

7/30/2008 7/30/2008 No No 6248 PAW 1 Hg Oct07

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

######## ######## No No 6248 PAW 1 Hg Oct09

other Hg CEM RATA The was a RATA test done on the unit's Hg CEM.

######## ######## No No

Page 80test_reports

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

Page 81test_report_configurations

facility _id report_id configuration_id 465 ARA4 Hg Sep05

Unit 4 469 CHE1 Hg Dec08

Unit 1 469 CHE2 Hg Aug05

Unit 2 469 CHE2 Hg Nov09

Unit 2 469 CHE2 Hg Oct08

Unit 2 469 CHE3 Hg Feb09

Unit 3 469 CHE3 Hg Jun07

Unit 3 469 CHE3 Hg Oct08

Unit 3 469 CHE4 Hg Aug05

Unit 4 469 CHE4 Hg Oct08

Unit 4 469 CHE4 Hg Oct09

Unit 4 470 COM1 Hg Apr07

Unit 1 470 COM1 Hg Mar09

Unit 1 470 COM1 Hg Oct07

Unit 1 470 COM1 Hg Sep06

Unit 1 470 COM2 Hg Apr09

Unit 2 470 COM2 Hg Dec07

Unit 2 470 COM2 Hg Sep06

Unit 2 477 VAL5 Hg Jan08

Unit 5 477 VAL5 Hg Jul09

Unit 5 525 HAY1 Hg Aug05

Unit 1 525 HAY1 Hg Feb09

Unit 1 525 HAY1 Hg Jan08

Unit 1 525 HAY1 Hg Jul09

Unit 1 525 HAY1 Hg Jun07

Unit 1 525 HAY1 Hg Sep07

Unit 1 525 HAY2 Hg Dec09

Unit 2 525 HAY2 Hg Jun07

Unit 2 525 HAY2 Hg Nov07

Unit 2 6248 PAW 1 Hg Aug05

Unit 1 6248 PAW 1 Hg Jul08

Unit 1 6248 PAW 1 Hg Oct07

Unit 1 6248 PAW 1 Hg Oct09

Unit 1

Page 82test_report_fuels

facility _id report_id fuel_id 465 ARA4 Hg Sep05

Coal 469 CHE1 Hg Dec08

Coal 469 CHE2 Hg Aug05

Coal 469 CHE2 Hg Nov09

Coal 469 CHE2 Hg Oct08

Coal 469 CHE3 Hg Feb09

Coal 469 CHE3 Hg Jun07

Coal 469 CHE3 Hg Oct08

Coal 469 CHE4 Hg Aug05

Coal 469 CHE4 Hg Oct08

Coal 469 CHE4 Hg Oct09

Coal 470 COM1 Hg Apr07

Coal 470 COM1 Hg Mar09

Coal 470 COM1 Hg Oct07

Coal 470 COM1 Hg Sep06

Coal 470 COM2 Hg Apr09

Coal 470 COM2 Hg Dec07

Coal 470 COM2 Hg Sep06

Coal 477 VAL5 Hg Jan08

Coal 477 VAL5 Hg Jul09

Coal 525 HAY1 Hg Aug05

Coal 525 HAY1 Hg Feb09

Coal 525 HAY1 Hg Jan08

Coal 525 HAY1 Hg Jul09

Coal 525 HAY1 Hg Jun07

Coal 525 HAY1 Hg Sep07

Coal 525 HAY2 Hg Dec09

Coal 525 HAY2 Hg Jun07

Coal 525 HAY2 Hg Nov07

Coal 6248 PAW 1 Hg Aug05

Coal 6248 PAW 1 Hg Jul08

Coal 6248 PAW 1 Hg Oct07

Coal 6248 PAW 1 Hg Oct09

Coal

Page 83test_report_fuel_types

facility _id report_id fuel_id fuel_type percentage_massvol percentage_btu

other_type 465 ARA4 Hg Sep05

Coal coal - subbituminous 100 100 469 CHE1 Hg Dec08

Coal coal - bituminous 100 100 469 CHE2 Hg Aug05

Coal coal - bituminous 100 100 469 CHE2 Hg Nov09

Coal coal - bituminous 100 100 469 CHE2 Hg Oct08

Coal coal - bituminous 100 100 469 CHE3 Hg Feb09

Coal coal - bituminous 100 100 469 CHE3 Hg Jun07

Coal coal - bituminous 100 100 469 CHE3 Hg Oct08

Coal coal - bituminous 100 100 469 CHE4 Hg Aug05

Coal coal - bituminous 100 100 469 CHE4 Hg Oct08

Coal coal - bituminous 100 100 469 CHE4 Hg Oct09

Coal coal - bituminous 100 100 470 COM1 Hg Apr07

Coal coal - subbituminous 100 100 470 COM1 Hg Mar09

Coal coal - subbituminous 100 100 470 COM1 Hg Oct07

Coal coal - subbituminous 100 100 470 COM1 Hg Sep06

Coal coal - subbituminous 100 100 470 COM2 Hg Apr09

Coal coal - subbituminous 100 100 470 COM2 Hg Dec07

Coal coal - subbituminous 100 100 470 COM2 Hg Sep06

Coal coal - subbituminous 100 100 477 VAL5 Hg Jan08

Coal coal - bituminous 100 100 477 VAL5 Hg Jul09

Coal coal - bituminous 100 100 525 HAY1 Hg Aug05

Coal coal - bituminous 100 100 525 HAY1 Hg Feb09

Coal coal - bituminous 100 100 525 HAY1 Hg Jan08

Coal coal - bituminous 100 100 525 HAY1 Hg Jul09

Coal coal - bituminous 100 100 525 HAY1 Hg Jun07

Coal coal - bituminous 100 100 525 HAY1 Hg Sep07

Coal coal - bituminous 100 100 525 HAY2 Hg Dec09

Coal coal - bituminous 100 100 525 HAY2 Hg Jun07

Coal coal - bituminous 100 100 525 HAY2 Hg Nov07

Coal coal - bituminous 100 100 6248 PAW 1 Hg Aug05

Coal coal - subbituminous 100 100 6248 PAW 1 Hg Jul08

Coal coal - subbituminous 100 100 6248 PAW 1 Hg Oct07

Coal coal - subbituminous 100 100 6248 PAW 1 Hg Oct09

Coal coal - subbituminous 100 100

Page 84cem_data

facility _id tim e_period

cem_period_description 465 Not Applicable

Not Applicable 469 1/1/2009 to present

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. 470 1/1/2007 to present

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2007. 477 1/1/2009 to present

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. 525 1/1/2009 to present

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. 6248 1/1/2009 to present

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009.

Page 85cem_data

A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2007. A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009. A summary

of mercury

emissions from a CEMS installed on this unit began to be submitted quarterly to the CDPHE in 2009.

Page 86cem_data_pollutants1

facility _id tim e_period

pollutant_nam e 6248 1/1/2009 to present

Total Mercury

(Hgt) 6248 1/1/2009 to present

Nitrogen Oxide (NOx) 6248 1/1/2009 to present

Sulfur Dioxide (SO2) 525 1/1/2009 to present

Nitrogen Oxide (NOx) 525 1/1/2009 to present

Sulfur Dioxide (SO2) 525 1/1/2009 to present

Total Mercury

(Hgt) 469 1/1/2009 to present

Nitrogen Oxide (NOx) 469 1/1/2009 to present

Sulfur Dioxide (SO2) 469 1/1/2009 to present

Total Mercury

(Hgt) 470 1/1/2007 to present

Nitrogen Oxide (NOx) 470 1/1/2007 to present

Sulfur Dioxide (SO2) 470 1/1/2007 to present

Total Mercury

(Hgt) 477 1/1/2009 to present

Nitrogen Oxide (NOx) 477 1/1/2009 to present

Sulfur Dioxide (SO2) 477 1/1/2009 to present

Total Mercury

(Hgt) 465 Not Applicable

Nitrogen Oxide (NOx) 465 Not Applicable

Sulfur Dioxide (SO2)

Page 87test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_bypass_percent

testing_bypass_percent 465 ARA4 Hg Sep05

Stack4 No No 469 CHE1 Hg Dec08

Stack1 No No 469 CHE2 Hg Aug05

Stack2 No No 469 CHE2 Hg Nov09

Stack1 No No 469 CHE2 Hg Oct08

Sack2 No No 469 CHE3 Hg Feb09

Stack3 No No 469 CHE3 Hg Jun07

Stack3 No No 469 CHE3 Hg Oct08

Sack3 No No 469 CHE4 Hg Aug05

Stack4 No No 469 CHE4 Hg Oct08

Sack4 No No 469 CHE4 Hg Oct09

Sack4 No No 470 COM1 Hg Apr07

Stack1 No No 470 COM1 Hg Mar09

Stack1 No No 470 COM1 Hg Oct07

Stack1 No No 470 COM1 Hg Sep06

Stack1 No No 470 COM2 Hg Apr09

Stack2 No No 470 COM2 Hg Dec07

Stack2 No No 470 COM2 Hg Sep06

Stack2 No No 477 VAL5 Hg Jan08

Stack5 No No 477 VAL5 Hg Jul09

Stack5 No No 525 HAY1 Hg Aug05

Stack1 No No 525 HAY1 Hg Feb09

Stack1 No No 525 HAY1 Hg Jan08

Stack1 No No 525 HAY1 Hg Jul09

Stack1 No No 525 HAY1 Hg Jun07

Stack1 No No 525 HAY1 Hg Sep07

Stack1 No No 525 HAY2 Hg Dec09

Stack2 No No 525 HAY2 Hg Jun07

Stack2 No No 525 HAY2 Hg Nov07

Stack2 No No 6248 PAW 1 Hg Aug05

Stack1 No No 6248 PAW 1 Hg Jul08

Stack1 No No 6248 PAW 1 Hg Oct07

Stack1 No No 6248 PAW 1 Hg Oct09

Stack1 No No

Page 88test_report_sampling

fg_fraction

Page 89sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 465 ARA4 Hg Sep05

Stack4 average 9/7/2005 9/8/2005 110 10.7 469 CHE1 Hg Dec08

Stack1 average 12/5/2008 12/5/2008 107.6 8.9 469 CHE2 Hg Aug05

Stack2 average 8/30/2005 8/30/2005 108 8.11 469 CHE2 Hg Nov09

Stack1 average ######## ######## 101 7 469 CHE2 Hg Oct08

Sack2 average ######## ######## 108.3 6.3 469 CHE3 Hg Feb09

Stack3 average 2/10/2009 2/10/2009 158.2 11.1 469 CHE3 Hg Jun07

Stack3 average 6/5/2007 6/5/2007 146 11 469 CHE3 Hg Oct08

Sack3 average ######## ######## 138.7 10.4 469 CHE4 Hg Aug05

Stack4 average 8/31/2005 9/1/2005 372 12.5 469 CHE4 Hg Oct08

Sack4 average ######## ######## 377.2 12 469 CHE4 Hg Oct09

Sack4 average 10/6/2009 10/7/2009 355.5 12.4 470 COM1 Hg Apr07

Stack1 average 4/26/2007 5/2/2007 342 11.2 470 COM1 Hg Mar09

Stack1 average 3/4/2009 3/9/2009 339.4 10.8 470 COM1 Hg Oct07

Stack1 average 10/2/2007 10/5/2007 470 COM1 Hg Sep06

Stack1 average 9/28/2006 10/3/2006 344.6 10.64 470 COM2 Hg Apr09

Stack2 average 4/6/2009 4/7/2009 358.6 12.4 470 COM2 Hg Dec07

Stack2 average ######## ######## 332 9.7 470 COM2 Hg Sep06

Stack2 average 9/15/2006 10/5/2006 358.4 10.8 477 VAL5 Hg Jan08

Stack5 average 1/22/2008 1/22/2008 191.7 10.9 477 VAL5 Hg Jul09

Stack5 average 7/23/2009 7/23/2009 191.1 12.2 525 HAY1 Hg Aug05

Stack1 average 8/25/2005 8/26/2005 202 12.8 525 HAY1 Hg Feb09

Stack1 average 2/12/2009 2/12/2009 198.2 12.5 525 HAY1 Hg Jan08

Stack1 average 1/24/2008 1/24/2008 200.3 525 HAY1 Hg Jul09

Stack1 average 7/20/2009 7/21/2009 195.7 13.7 525 HAY1 Hg Jun07

Stack1 average 6/19/2007 6/19/2007 11.7 525 HAY1 Hg Sep07

Stack1 average 9/25/2007 9/25/2007 201 12.7 525 HAY2 Hg Dec09

Stack2 average ######## ######## 281.5 13.7 525 HAY2 Hg Jun07

Stack2 average 6/21/2007 6/21/2007 15 525 HAY2 Hg Nov07

Stack2 average 11/1/2007 11/1/2007 282 13.6 6248 PAW 1 Hg Aug05

Stack1 average 8/23/2005 8/23/2005 532 11.4 6248 PAW 1 Hg Jul08

Stack1 average 7/30/2008 7/30/2008 537.3 10.5 6248 PAW 1 Hg Oct07

Stack1 average ######## ######## 530 11.6 6248 PAW 1 Hg Oct09

Stack1 average ######## ######## 536.9 11.6

Page 90sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 300000 dscfm 6.6 13 0

278000 dscfm 4.9 13.7 295 12.2

12.7 7.5 13 170 5.9 11.9 827000 dscfm 5.7 13.2 170 14.2 14.6 6.1 13.7 0

13.2

6.2 13.4 0

13.4 6 14 244 6.2 13.6 278.4 458485 dscfm 6 13.2 143 12.8 560000 dscfm 4.5 11.6 170 13.3 13.2 170 13.1 6 13 175 478312 dscfm 6 13 179

5 15 174 627288 dscfm 5.5 14.5 163 1240000 dscfm 5.53 13.4 0 0 6.5 14 0

14.2

Page 91sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value 0.003 Methods 1-4 and Ontario Hydro

EPA Method 30B 0.003 Methods 1-4 and Ontario Hydro

EPA Method 30B EPA Method 30B EPA Method 30B 0.003 Methods 1-4 and Ontario Hydro

EPA Method 30B 0.007 Methods 1-4 and Ontario Hydro

EPA Method 30B EPA Test Method 30B Methods 1-4 and Ontario Hydro EPA Test Method 30B Methods 1-4 and Ontario Hydro Methods 1-4 and Ontario Hydro EPA Test Method 30B Methods 1-4 and Ontario Hydro Methods 1-4 and Ontario Hydro Ontario Hydro EPA Test Method 30B 0.006 Methods 1-4 and Ontario Hydro

EPA Test Method 30B EPA Method 30B EPA Test Method 30B 0.001 Methods 1-4 and Ontario Hydro

Methods 1-4 and Ontario Hydro EPA Test Method 30B 0.0006 Methods 1-4 and Ontario Hydro 0.0006 Methods 1-4 and Ontario Hydro 0.004 Methods 1-4 and Ontario Hydro

EPA Method 30B Methods 1-4 and Ontario Hydro EPA Test Method 30B

Page 92sampling_runs

fuel_sulfur

Page 93sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 6248 PAW 1 Hg Oct07

Stack1 average Particulate-bound Mercury (Hgp) 0 microgram per dry

standard cubic meter ( FALSE 6248 PAW 1 Hg Oct07

Stack1 average Oxidized Mercury (Hg++) 0 microgram per dry

standard cubic meter ( FALSE 6248 PAW 1 Hg Oct07

Stack1 average Elem ental Mercury (Hg0) 7.13 microgram per dry standard cubic meter ( FALSE 6248 PAW 1 Hg Oct07

Stack1 average Total Mercury (Hgt) 7.13 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Apr07

Stack1 average Particulate-bound Mercury (Hgp) 0 microgram per dry

standard cubic meter ( FALSE 470 COM1 Hg Apr07

Stack1 average Oxidized Mercury (Hg++) 1.07 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Apr07

Stack1 average Elem ental Mercury (Hg0) 5.99 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Apr07

Stack1 average Total Mercury (Hgt) 7.07 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Sep06

Stack2 average Oxidized Mercury (Hg++) 4.43 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Sep06

Stack2 average Elem ental Mercury (Hg0) 1.7 microgram per dry

standard cubic meter ( FALSE 470 COM2 Hg Sep06

Stack2 average Total Mercury (Hgt) 6.17 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Sep06

Stack1 average Oxidized Mercury (Hg++) 2.08 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Sep06

Stack1 average Elem ental Mercury (Hg0) 4.64 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Sep06

Stack1 average Total Mercury (Hgt) 6.72 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Oct07

Stack1 average Particulate-bound Mercury (Hgp) 0 microgram per dry

standard cubic meter ( FALSE 470 COM1 Hg Oct07

Stack1 average Oxidized Mercury (Hg++) 0 microgram per dry

standard cubic meter ( FALSE 470 COM1 Hg Oct07

Stack1 average Elem ental Mercury (Hg0) 7.89 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Oct07

Stack1 average Total Mercury (Hgt) 7.89 microgram per dry standard cubic meter ( FALSE 469 CHE2 Hg Oct08

Sack2 average Total Mercury (Hgt) 0.14 microgram per dry standard cubic meter ( FALSE 469 CHE3 Hg Oct08

Sack3 average Total Mercury (Hgt) 0.033 microgram per dry standard cubic meter ( FALSE 469 CHE1 Hg Dec08

Stack1 average Total Mercury (Hgt) 0.18 microgram per dry standard cubic meter ( FALSE 469 CHE4 Hg Oct08

Sack4 average Total Mercury (Hgt) 0.04 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Jan08

Stack1 average Total Mercury (Hgt) 0.49 microgram per dry standard cubic meter ( FALSE 6248 PAW 1 Hg Jul08

Stack1 average Total Mercury (Hgt) 8.9 microgram per dry

standard cubic meter ( FALSE 477 VAL5 Hg Jan08

Stack5 average Oxidized Mercury (Hg++) 0.03 microgram per dry standard cubic meter ( FALSE 477 VAL5 Hg Jan08

Stack5 average Elem ental Mercury (Hg0) 0.59 microgram per dry standard cubic meter ( FALSE 477 VAL5 Hg Jan08

Stack5 average Total Mercury (Hgt) 0.62 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Jun07

Stack2 average Particulate-bound Mercury (Hgp) 0.03 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Jun07

Stack2 average Oxidized Mercury (Hg++) 0.12 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Jun07

Stack2 average Elem ental Mercury (Hg0) 0.72 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Jun07

Stack2 average Total Mercury (Hgt) 0.86 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Dec07

Stack2 average Oxidized Mercury (Hg++) 1.25 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Dec07

Stack2 average Elem ental Mercury (Hg0) 0.16 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Dec07

Stack2 average Total Mercury (Hgt) 1.4 microgram per dry

standard cubic meter ( FALSE 469 CHE2 Hg Nov09

Stack1 average Total Mercury (Hgt) 0.16 microgram per dry standard cubic meter ( FALSE 469 CHE3 Hg Feb09

Stack3 average Total Mercury (Hgt) 0.11 microgram per dry standard cubic meter ( FALSE 469 CHE4 Hg Oct09

Sack4 average Total Mercury (Hgt) 0.25 microgram per dry standard cubic meter ( FALSE 470 COM1 Hg Mar09

Stack1 average Total Mercury (Hgt) 0.77 microgram per dry standard cubic meter ( FALSE 470 COM2 Hg Apr09

Stack2 average Total Mercury (Hgt) 0.79 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Dec09

Stack2 average Total Mercury (Hgt) 0.6 microgram per dry

standard cubic meter ( FALSE 525 HAY1 Hg Jul09

Stack1 average Total Mercury (Hgt) 0.36 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Feb09

Stack1 average Total Mercury (Hgt) 0.29 microgram per dry standard cubic meter ( FALSE 6248 PAW 1 Hg Oct09

Stack1 average Total Mercury (Hgt) 10.61 microgram per dry standard cubic meter ( FALSE 477 VAL5 Hg Jul09

Stack5 average Total Mercury (Hgt) 0.05 microgram per dry standard cubic meter ( FALSE 465 ARA4 Hg Sep05

Stack4 average Particulate-bound Mercury (Hgp) 0.00538 microgram per dry standard cubic meter ( FALSE 465 ARA4 Hg Sep05

Stack4 average Oxidized Mercury (Hg++) 4.4 microgram per dry

standard cubic meter ( FALSE 465 ARA4 Hg Sep05

Stack4 average Elem ental Mercury (Hg0) 2.19 microgram per dry standard cubic meter ( FALSE 465 ARA4 Hg Sep05

Stack4 average Total Mercury (Hgt) 6.6 microgram per dry

standard cubic meter ( FALSE 6248 PAW 1 Hg Aug05

Stack1 average Particulate-bound Mercury (Hgp) 0.00787 microgram per dry standard cubic meter ( FALSE 6248 PAW 1 Hg Aug05

Stack1 average Oxidized Mercury (Hg++) 1.58 microgram per dry standard cubic meter ( FALSE 6248 PAW 1 Hg Aug05

Stack1 average Elem ental Mercury (Hg0) 6.83 microgram per dry standard cubic meter ( FALSE

Page 94sampling_run_pollutants1

6248 PAW 1 Hg Aug05

Stack1 average Total Mercury (Hgt) 8.42 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Aug05

Stack1 average Particulate-bound Mercury (Hgp) 0.00734 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Aug05

Stack1 average Oxidized Mercury (Hg++) 0.149 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Aug05

Stack1 average Elem ental Mercury (Hg0) 2.97 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Aug05

Stack1 average Total Mercury (Hgt) 3.12 microgram per dry standard cubic meter ( FALSE 469 CHE2 Hg Aug05

Stack2 average Particulate-bound Mercury (Hgp) 0.0145 microgram per dry standard cubic meter ( FALSE 469 CHE2 Hg Aug05

Stack2 average Oxidized Mercury (Hg++) 0.145 microgram per dry standard cubic meter ( FALSE 469 CHE2 Hg Aug05

Stack2 average Elem ental Mercury (Hg0) 2.81 microgram per dry standard cubic meter ( FALSE 469 CHE2 Hg Aug05

Stack2 average Total Mercury (Hgt) 2.97 microgram per dry standard cubic meter ( FALSE 469 CHE4 Hg Aug05

Stack4 average Particulate-bound Mercury (Hgp) 0.00375 microgram per dry standard cubic meter ( FALSE 469 CHE4 Hg Aug05

Stack4 average Oxidized Mercury (Hg++) 0.0201 microgram per dry standard cubic meter ( FALSE 469 CHE4 Hg Aug05

Stack4 average Elem ental Mercury (Hg0) 1.3 microgram per dry

standard cubic meter ( FALSE 469 CHE4 Hg Aug05

Stack4 average Total Mercury (Hgt) 1.33 microgram per dry standard cubic meter ( FALSE 469 CHE3 Hg Jun07

Stack3 average Particulate-bound Mercury (Hgp) 0.02 microgram per dry standard cubic meter ( FALSE 469 CHE3 Hg Jun07

Stack3 average Oxidized Mercury (Hg++) 0 microgram per dry

standard cubic meter ( FALSE 469 CHE3 Hg Jun07

Stack3 average Elem ental Mercury (Hg0) 0.16 microgram per dry standard cubic meter ( FALSE 469 CHE3 Hg Jun07

Stack3 average Total Mercury (Hgt) 0.17 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Nov07

Stack2 average Particulate-bound Mercury (Hgp) 0.01 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Nov07

Stack2 average Oxidized Mercury (Hg++) 0.897 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Nov07

Stack2 average Elem ental Mercury (Hg0) 1.06 microgram per dry standard cubic meter ( FALSE 525 HAY2 Hg Nov07

Stack2 average Total Mercury (Hgt) 1.96 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Sep07

Stack1 average Particulate-bound Mercury (Hgp) 0 microgram per dry

standard cubic meter ( FALSE 525 HAY1 Hg Sep07

Stack1 average Oxidized Mercury (Hg++) 0.07 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Sep07

Stack1 average Elem ental Mercury (Hg0) 0.48 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Sep07

Stack1 average Total Mercury (Hgt) 0.56 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Jun07

Stack1 average Particulate-bound Mercury (Hgp) 0.03 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Jun07

Stack1 average Oxidized Mercury (Hg++) 0.06 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Jun07

Stack1 average Elem ental Mercury (Hg0) 0.54 microgram per dry standard cubic meter ( FALSE 525 HAY1 Hg Jun07

Stack1 average Total Mercury (Hgt) 0.62 microgram per dry standard cubic meter ( FALSE

Page 95sampling_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 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 6.47 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 6.47 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.99 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 5.52 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 6.53 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 4.15 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 1.57 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 5.71 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 1.95 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 4.35 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 6.3 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 7.31 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 7.31 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.48 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE 0.000061 pound per hour (lb/hr) FALSE 0.03 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. 0.0012 pound per hour (lb/hr)

FALSE 0.56 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. 0.0012 pound per hour (lb/hr)

FALSE 0.59 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.1 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.64 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.74 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 1.11 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.14 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 1.25 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. 6.13E-06 pound per hour (lb/hr) FALSE 0.00465 pound per trillion British Thermal Unit (lb/1012Btu) FALSE Actual results were <0.00512, <5.76E-06, and <0.00442. 0.00494 pound per hour (lb/hr)

FALSE 3.8 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00247 pound per hour (lb/hr)

FALSE 1.89 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0074 pound per hour (lb/hr)

FALSE 5.69 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 3.63E-05 pound per hour (lb/hr) FALSE 0.00664 pound per trillion British Thermal Unit (lb/1012Btu) FALSE Actual results were <0.00787, <3.63E-05, and <0.00664. 0.00736 pound per hour (lb/hr)

FALSE 1.32 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0317 pound per hour (lb/hr)

FALSE 5.71 pound per trillion British Thermal Unit (lb/1012Btu) FALSE

Page 96sampling_run_pollutants1

0.0391 pound per hour (lb/hr)

FALSE 7.04 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 1.54E-05 pound per hour (lb/hr) FALSE 0.00725 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.0003 pound per hour (lb/hr)

FALSE 0.134 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00618 pound per hour (lb/hr)

FALSE 2.87 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00649 pound per hour (lb/hr)

FALSE 3.01 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 1.51E-05 pound per hour (lb/hr) FALSE 0.0119 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.000151 pound per hour (lb/hr) FALSE 0.12 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00292 pound per hour (lb/hr)

FALSE 2.31 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00308 pound per hour (lb/hr)

FALSE 2.44 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 1.16E-05 pound per hour (lb/hr) FALSE 0.00318 pound per trillion British Thermal Unit (lb/1012Btu) FALSE Actual results were <0.00375, <1.16E-05, and <0.00318. 6.22E-05 pound per hour (lb/hr) FALSE 0.017 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00405 pound per hour (lb/hr)

FALSE 1.11 pound per trillion British Thermal Unit (lb/1012Btu) FALSE 0.00412 pound per hour (lb/hr)

FALSE 1.12 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.16 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.16 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.8 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.95 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 1.75 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.07 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.48 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.55 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.06 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.53 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units. FALSE 0.59 pound per trillion British Thermal Unit (lb/1012Btu) FALSE concentration values are actually wet but entry

will only let allow for dry

measure units.

Page 97sampling_run_pollutants1

run_pollutant_comment concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units.

concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units.

concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. Actual results were <0.00512, <5.76E-06, and <0.00442.

Actual results were <0.00787, <3.63E-05, and <0.00664.

Page 98sampling_run_pollutants1

Actual results were <0.00375, <1.16E-05, and <0.00318.

concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units. concentration values are actually wet but entry

will only let allow for dry

measure units.

Page 99sampling_run_fuel

facility _id report_id sampling_port_id run_id fuel_pollutant fuel_conc fuel_conc_units fuel_conc_ND

fuel_conc_MDL

Page 100sampling_run_fuel

fuel_conc_MDL

Page 101