Facility _Information facility _id utility

_code legal_owner_nam e

legl_operator_name

legal_address_ty pe

legal_address

legal_city legal_state legal_zip 1606 1606 Mt. Tom Generating Company , LLC FirstLight Power Resources Services, LLC

legal owner200 Northampton Street Holyoke MA 01040

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 Mount Tom 200 Northampton Street Holyoke MA 01040 200 Northampton Street Holyoke MA 01040

Page 2Facility _Information RFA_small_entity

ff_fired_coal

ff_fired_oil ff_fired_ngas ff_fired_petcoke

ff_fired_other

ff_permitted_coal

ff_permitted_oil

ff_permitted_ngas No TRUE TRUE FALSE FALSE FALSE TRUE TRUE FALSE

Page 3Facility _Information ff_permitted_petcoke

ff_permitted_other

deviation_reporting

continuous_emissions

cem_provided

facility _note FALSE FALSE Title V semi annual and annual reporting Yes other than Hg is reported through ECMPS to EPA (Region 1 Boston) No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 4Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 5Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 6Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 7Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 8Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 9Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 10Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 11Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 12Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 13Facility _Information No analysis provided for oil shipments because we have no data on HAPS or trace metals in oil (per guidance from RTI)RE coal shipments and analyses: analysis supplier and lab are same for shipments 1-5, remainder of shipments have no trace elements or HAP analyses. Copies of coal analyses are not being provided with the ICR per guidance from J. Cole at RTI. All available, requested coal analysis data is entered in the ICR. 4 ports identified are in stack after all controls ~150 ft above gradeStack velocity (68 ft/sec) is average of 12, flow-RATA runs in high load range (measured in 2009)RE Unit control technology demonstrations: Turbosorp dry flue gas desulfurization unit, for Hg and SO2 control, installed late in 2009 and is still undergoing commissioning, O&M figure is as budgeted for 2010 (NOT 2009) and may not be representative of annual cost given age of system.Notes re Emission test results:1) Flue gas flow for test results is SCFM wet2) Test of Oct 2005 was prior to SCR installa

Page 14facility _contacts facility _id contact_id contact_title contact_name

contact_phone1

contact_phone2

contact_email

contact_primary 1606 1 Station Services Manager Richard Merchant

4135369563 richard.merchant@gdfsuezna.com TRUE 1606 2 EHS Specialist Milon Harris

4135369571 mi lton.harris@gdfsuezna.com FALSE

Page 15facility _coal_utilized facility _id coal_ty pe percentage_mass percentage_btu

sy nfuel_ty pe

coal_note 1606 bitum inous 100 100 distillate oil used for start up only and not power generation

Page 16facility _coal_utilized distillate oil used for start up only and not power generation

Page 17facility _oil_utilized facility _id oil_ty pe percentage_volume percentage_btu

other_ty pe 1606 No.2 Fuel Oil (distillate) 100 100

Page 18facility _other_materials facility _id other_material

permitted_burn

actually _burn other_quantity

other_quantity

_units other_note rcra_utilize rcra_explain

Page 19facility _other_materials rcra_explain

Page 20boiler_information

facility _id boiler_id boiler_ty pe boiler_other bottom_design

design_fuel heat_input ma x_heat_input MW e_capacity 1606 1 Wa ll firing - front firing Dry Bottom coal 1480 1480 155

Page 21boiler_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 143.6 89 89 2150 1950 1000 1000 FALSE 1000

Page 22boiler_information

design_reheat_temp2

operating_reheat_multiple

operating_reheat_temp1

operating_reheat_temp2

hours_operated

vg_capacity

_factor applicable_NSPS

retirement_year

retirement_year_CBI FALSE 1000 7390 70.7 N TRUE

Page 23boiler_information

NOx_control

SO2_control

combustion_additives Yes No No

Page 24boiler_fuels

facility _id boiler_id fuel_ty pe fuel_year percentage_massvol percentage_btu

other_ty pe 1606 1 coal - bituminous 2007 100 100 1606 1 coal - bituminous 2008 100 100 1606 1 coal - bituminous 2009 100 100

Page 25boiler_control_NOx

facility _id boiler_id NOx_ty pe NOx_other NOx_online 1606 1 Low NOx Burner 1/1/1995

Page 26boiler_control_SO2

facility _id boiler_id SO2_ty pe SO2_other SO2_online

Page 27boiler_additives

facility _id boiler_id boiler_additive additive_other

additive_online

Page 28facility _units facility _id unit_id 1606 1

Page 29unit_boilers

facility _id unit_id boiler_id 1606 1 1

Page 30facility _controls facility _id control_id control_group control_ty pe

control_other

legacy _control cntrol_online

control_offline

NOx_reagent 1606 BH1 PM control Fabric Filter, pulse FALSE 12/1/2009 1606 ESP1 PM control Electrostatic precipitator, cold side, w/o flue gas conditioning FALSE 9/1/1982 1606 SCR1 NOx control Selective Cataly

tic Reduction FALSE 6/1/2006 Am mo nia 1606 TS1 SO2 control Circulating Dry

Scrubber FALSE 12/1/2009

Page 31facility _controls reagent_other

NOx_ammonia

SO2_sorbent

oher_sorbent

SO2_scrubber_additive 19 Lim e ye s

Page 32facility _sampling_ports facility _id sampling_port_id 1606 P1 1606 P2 1606 P3 1606 P4

Page 33facility _stacks facility _id stack_id stack_height stack_diameter

sack_gas_velocity 1606 STK1 370 13 68

Page 34configurations

facility _id configuration_id 1606 1 current

Page 35configuration_components

facility _id configuration_id

component_id

order component_ty pe port_near 1606 1 current 1 1 Unit 1606 1 current BH1 5 PM control 1606 1 current ESP1 3 PM control 1606 1 current SCR1 2 NOx control 1606 1 current STK1 6 Stack 1606 1 current TS1 4 SO2 control

Page 36configuration_pollutants1

facility _id configuration_id

pollutant_nam e

permit_ty pe_1

em lim it_1 em lim it_units_1 avg_period_1

em lim it_2 em lim it_units_2 1606 1 current Total Suspended Particulates (TSP) Federal - Title V Operating Permit

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

Continuous 1606 1 current Sulfur Dioxide (SO2) Federal - Title V Operating Permit

0.006 pound per Gigawatt hour (lb/GW h)

30 days 1606 1 current Total Mercury (Hgt) Federal - Title V Operating Permit

0.0075 pound per Gigawatt hour (lb/GW h)

24 hours 1606 1 current Carbon Monoxide (CO) Federal - Title V Operating Permit

200 parts per million by volum e (dry ) (ppmvd) 24 hours 1606 1 current Nitrogen Oxide (NOx) Federal - Title V Operating Permit

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

24 hours

Page 37configuration_pollutants1

avg_period_2

em lim it_3 em lim it_units_3 avg_period_3

em lim it_4 em lim it_units_4 avg_period_4

em lim it_details

test_method SO2 lim its are:3 lb/MW h as 12-month rolling average6 lb/MW h as a monthly average1.2 lb/MMBtu as calendar year average Hg lim it is based upon State regulation: 0.0075 lb/GW h as a 12-month rolling average (NOT a 24 hour average - 24 hrs entered per Q&A guidance) NOx limit is 1.5 lb/MW h 12-month rolling average and 3 lb/MW h monthly average

Page 38configuration_pollutants1

em rate em rate_units guarantee_level

_explain

req_monitoring

eq_recordkeeping

req_reporting 0.04 pound per million British Thermal Unit (lb/MMBtu)

No actual guarantee Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) years from date of record and shall be made available to the Department upon request. 0.006 pound per Gigawatt hour (lb/GW h)

No guaranteed min 95% reduction, 24 hr average measured at CEM and corrected to 3% O2 and assuming coal sulfur content 1.5%, rate entered here to satisfy completeness requirement of ICR Monitoring, Title V, Table 4:5) In accordance with the Acid Rain Program 40 CFR Part 72 and 310 CMR 7.14(2), Mt. Tom shall monitor SO2 emissions with CEMS meeting the requirements of 40 CFR Part 75 and use the procedures contained therein to gather and analy ze data, provide quality assurance and quality

control. Compliance with 40 CFR Part 75 shall constitute compliance with this requirement.9) Mt. tom shall use the substitution procedures for missing data specified in 40 CFR Part 75 Subpart D and/or 40 CFR Part 75 §75.70(f) whenever the CEMS fail to measure and record a valid quality-assured hour of data for SO2, NOx, CO2, exhaust flow, or heat input.17) In accordance with approval 1-E-01-072 and 310 CMR 7.29, actual emissions shall be monitored for the individual unit in the calculation for demonstrating compliance. Actual emissions shall be monitored in accordance with 40 CFR Part 75 for SO2, CO2, and NOx. The Department shall detail the monitoring methodology for Hg, CO and PM 2.5 at the time reg Recordkeeping, Title V, Table 5:1) In accordance with 40 CFR Part 75, 310 CMR 7.19(13)(a)1., 310 CMR 7.19(13)(b)1 through 7.19(13)(b)12, 40 CFR Part 60, Appendix B, and 40 CFR Part 60 Appendix F, Mt. Tom shall record the emissions of NOx, CO, SO2, CO2, and the flue gas opacity and volum etric flow rate on a continuous basis.5) In accordance with 310 CMR 7.00: Appendix C(9)(b)2., Mt. Tom shall keep and maintain fuel analysis results used to demonstrate compliance with fuel sulfur and ash content requirements.9) In accordance with 40 CFR Part 75 §75.53, Mt. Tom shall prepare and maintain a monitoring plan containing sufficient information on the CEMS and COMS to demonstrate that all emissions of SO2, NOx, CO2, and opacityare monitored and reported. Mt. Tom shall update the monitoring plan whenever it makes a replacement, modification, or change in the certified CEMS and/or COMS, including a change in the automated data acquisition and handling system or in the flue gas handling system. The monitoring pl Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. 0.0075 pound per Gigawatt hour (lb/GW h)

Yes vendor would not guarantee, guaranteed rate entered to satisfy completeness requirements of ICR Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio 200 parts per million by volum e (dry ) (ppmvd) No no guaranteed rate, value entered to satisfy completeness requirement of ICR Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio 0.06 pound per million British Thermal Unit (lb/MMBtu)

No less than or = 0.060 lb/MMBtu, 24-hr average

Page 39configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) years from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 40configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 41configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 42configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 43configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 44configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 45configuration_pollutants1 Recordkeeping, Title V Table 5:24) In accordance with approval 1-P-05-031, Mt. Tom shall generate monthly reports in-house that document fuel use and compliance with the 12% per cargo and 9% per 12 rolling month ash limits. If any lim its are exceeded, Mt. Tom shall notify the Department in writing no later than the 15th day of the following month.25) In accordance with approval 1-P-05-031, Mt. Tom shall maintain coal certification, including coal supplier and % ash per shipment, and coal purchase records at the facility . These records shall be kept on site for five (5) y ears from date of record and shall be made available to the Department upon request. Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 46configuration_pollutants1
Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 47configuration_pollutants1
Reporting, Title V Table 6:3) In accordance with Department Approval No. 1-B-90-099, MT. TOM shall submit SO2 emission reports for each calendar quarter to verify compliance with the Massachusetts Acid Rain Law, 310 CMR 7.22. Said reports shall be submitted by the 30th day

of April, July , October, and January covering the previous calendar periods of January through March, April through June, July through September, and October through December, respectively . For each fuel utilization facility that is part of the acid rain control plan, said reports shall contain a monthly summary

and a calendar year to date summary of:a.the ty pe(s) of fuel burned;b.the quantity of each fuel (gallons, tons, or cubic feet), the sulfur content of each fuel (pounds per million Btu and percent by weight); and c.the average heating value (Btu per gallon, ton, or cubic foot) of each fuel burned. Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 48configuration_pollutants1

Monitoring Requirements, Title V, Table 4:26) In accordance with 310 CMR 7.29(5)(a)3.g.i, by January 1, 2008, Mt. Tom shall install, certify , and operate a Hg CEMS. Mt. Tom shall:(i) submit a preliminary CEMS m onitoring plan for Department approval at least 180 days prior to equipment installation;(ii) include the following information in the preliminary CEMS m onitoring plan: source identification, source description, control technology description, the applicable regulations, the ty pe of monitor, a monitoring system flow diagram, a description of the data handling system, and a sample calculation demonstrating compliance with the emission limits using conversion factors from 40 CFR Part 60 or Part 75 or other proposed factors;(iii) submit for Department approval a CEMS certification protocol at least 90 day s prior to certification testing for the CEMS, and any proposed adjustment to the certification testing at least seven days in advance; (iv) include the following information in the certificatio Monitoring, Title V Table 4:2) In accordance with Approval No. 1-B-94-011, the programmable logic controller serving the CEMS shall be programmed to obtain readings from the NOx and CO monitor at least every 10 seconds and compute 15-minute block averages as well as one hour averages as specified by 310 CMR 7.19(13)(b)9. Mt. Tom shall calculate the NOx emission rate using the procedures specified in 40 CFR Part 75 Appendix F, Conversion Procedures.3) In accordance with 310 CMR 7.19(13)(b)10., Mt. Tom shall operate its CEMS at all times that the emission unit is operating except for periods of CEMS calibration checks, zero span adjustment, reasonable maintenance, and periods of unexpected and unavoidable failure of the equipment. Notwithstanding such exceptions, in all cases Mt. Tom shall obtain valid data for at least 75% of the hours per day , 75% of the days per month, and 90% of the hours per quarter during which the emission unit is operating. This requirement applies to the monitoring of CO emissio

Page 49control_technologies

facility _id configuration_id

component_id

control_id project_title project_ty pe vendor_name

vndor_contact

vendor_phone 1606 1 current TS1 1 Turbosorp DFGD Non-Demonstration

Babcock Power, Inc.

Daniel Douthright

5088543812

Page 50control_technologies

vendor_address

vndor_city

vendor_state

vendor_zip actual_start_date projected_start_date

end_date sorbent chemical_additive 5 Neponset St

Wo rcester MA 01606 ######## powdered activated carbon or BPAC

Page 51control_technologies

injection_point

HAP_em ission_reduction

HAP_em ission_rate

HAP_em ission_rate_units

HAP_achieved_reduction

HAP_achieved_rate

HAP_achieved_rate_units

feed_rate feed_rate_units upstream of reactor and after ESP

90 2.5E-06 lb/MW h 95 5 lb/MMACF

Page 52control_technologies feed_rate_units

Page 53control_coal_ranks

facility _id configuration_id

component_id

control_id coal_ty pe 1606 1 current TS1 1 bitum inous

Page 54control_pollutants1

facility _id configuration_id

component_id

control_id pollutant_nam e 1606 1 current TS1 1 Total Mercury (Hgt)

Page 55control_costs

facility _id configuration_id

component_id

control_id boiler_retrofit boiler_new_install

total_capital_investm ent

total_operating_costs

base_year 1606 1 current TS1 1 Yes No 54000000 3600000 2009

Page 56control_costs

CBI FALSE

Page 57mi sc_controls

facility _id mi sc_control_id

control_description 1606 1 Em ission controls include the following: use of low sulfur & low ash coal, SCR with ammonia injection for NOx, ESP for particulate control, Turbosorp dry flue gas desulfurization system followed by a finishing baghouse for PM control.

Page 58mi sc_controls
Em ission controls include the following: use of low sulfur & low ash coal, SCR with ammonia injection for NOx, ESP for particulate control, Turbosorp dry flue gas desulfurization system followed by a finishing baghouse for PM control.

Page 59mi sc_controls
Em ission controls include the following: use of low sulfur & low ash coal, SCR with ammonia injection for NOx, ESP for particulate control, Turbosorp dry flue gas desulfurization system followed by a finishing baghouse for PM control.

Page 60mi sc_control_configurations

facility _id mi sc_control_id

configuration_id 1606 1 1 current

Page 61fuel_shipments

facility _id shipment_id

shipment_date

am ount_received

am ount_units

fuel_ty pe state_country other_country

county 1606 1 1/1/2009 38807 short tons (2000 lbs) coal Other Colom bia 1606 2 3/1/2009 35670 short tons (2000 lbs) coal Other Colom bia 1606 3 4/1/2009 38400 short tons (2000 lbs) coal Other Colom bia 1606 4 4/1/2009 39424 short tons (2000 lbs) coal Other Colom bia 1606 5 7/1/2009 40115 short tons (2000 lbs) coal Other Colom bia 1606 6 7/1/2009 7602 short tons (2000 lbs) coal WV 1606 7 8/1/2009 7715 short tons (2000 lbs) coal PA 1606 8 9/1/2009 7683 short tons (2000 lbs) coal PA

Page 62fuel_shipments

coal_seam shipment_method

Barge Barge Barge Barge Barge Pittsburgh Unit Train

Unit Train Unit Train

Page 63fuel_shipment_configurations

facility _id shipment_id

configuration_id 1606 1 1 current 1606 2 1 current 1606 3 1 current 1606 4 1 current 1606 5 1 current 1606 6 1 current 1606 7 1 current 1606 8 1 current

Page 64fuel_shipment_samples

facility _id shipment_id

sample_id am ount_fuel am ount_fuel_units

total_sulfur ash_content heating_value

hating_units 1606 1 1 0.43 6.95 11369 Btu/lb 1606 2 1 0.46 7.72 11187 Btu/lb 1606 3 1 0.44 6.54 11511 Btu/lb 1606 4 1 0.49 7.92 11346 Btu/lb 1606 5 1 0.71 6.4 12196 Btu/lb 1606 6 1 3.09 8.75 13334 Btu/lb 1606 7 1 2.06 8.62 13994 Btu/gal 1606 8 1 2.13 8.73 13904 Btu/lb

Page 65fuel_shipment_samples

chlorine chlorine_units fluorine fluorine_units data_provided

data_other_specified

supplier_ty pe

supplier_name

supplier_address 0.03 percent (dry ) (%) contractual obligations Fuel supplier Glencore, LTD

301 Tresser Blvd 0.03 percent (dry ) (%) contractual obligations Fuel supplier 0.03 percent (dry ) (%) contractual obligations Fuel supplier 0.03 percent (dry ) (%) contractual obligations Fuel supplier 0.03 percent (dry ) (%) contractual obligations Fuel supplier contractual obligations Fuel supplier contractual obligations Fuel supplier contractual obligations Fuel supplier

Page 66fuel_shipment_samples

supplier_city

supplier_state

supplier_zip

lab_nam e lab_address lab_city lab_state lab_zip analysis_copies Stam ford CT 06901 Incolab Services Colombia LTDA. Km 2-25 Troncal del Caribe Via a Gaira

Santa Marta, Magdalena, Colombia No No No No No No No No

Page 67fuel_shipment_samples analysis_copies

Page 68fuel_sample_pollutants

facility _id shipment_id

sample_id fuel_pollutant pollutant_conc

pollutant_conc_units

pollutant_conc_ND

pollutant_conc_MDL 1606 1 1 Arsenic (As) parts per million (dry ) (ppm) TRUE 4 1606 1 1 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 1 1 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 1 1 Chromium (Cr) 7 parts per million (dry ) (ppm) FALSE 1606 1 1 Lead (Pb) 3 parts per million (dry ) (ppm) TRUE 4 1606 1 1 Manganese (Mn) 39 parts per million (dry ) (ppm) FALSE 1606 1 1 Nickel (Ni) 7 parts per million (dry ) (ppm) FALSE 1606 1 1 Selenium (Se) 3 parts per million (dry ) (ppm) TRUE 4 1606 2 1 Arsenic (As) parts per million (dry ) (ppm) TRUE 5 1606 2 1 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 2 1 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 2 1 Chromium (Cr) 12 parts per million (dry ) (ppm) FALSE 1606 2 1 Lead (Pb) parts per million (dry ) (ppm) TRUE 5 1606 2 1 Manganese (Mn) 63 parts per million (dry ) (ppm) FALSE 1606 2 1 Mercury (Hg) 0.054 parts per million (dry ) (ppm) FALSE 1606 2 1 Nickel (Ni) 10 parts per million (dry ) (ppm) FALSE 1606 2 1 Selenium (Se) parts per million (dry ) (ppm) TRUE 5 1606 3 1 Arsenic (As) parts per million (dry ) (ppm) TRUE 5 1606 3 1 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 3 1 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 3 1 Chromium (Cr) 11 parts per million (dry ) (ppm) FALSE 1606 3 1 Lead (Pb) parts per million (dry ) (ppm) TRUE 4 1606 3 1 Manganese (Mn) 41 parts per million (dry ) (ppm) FALSE 1606 3 1 Mercury (Hg) 0.06 parts per million (dry ) (ppm) FALSE 1606 3 1 Nickel (Ni) 10 parts per million (dry ) (ppm) FALSE 1606 3 1 Selenium (Se) parts per million (dry ) (ppm) TRUE 4 1606 4 1 Arsenic (As) parts per million (dry ) (ppm) TRUE 4 1606 4 1 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 4 1 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 4 1 Chromium (Cr) 14 parts per million (dry ) (ppm) FALSE 1606 4 1 Lead (Pb) parts per million (dry ) (ppm) TRUE 4 1606 4 1 Manganese (Mn) 35 parts per million (dry ) (ppm) FALSE 1606 4 1 Mercury (Hg) 0.052 parts per million (dry ) (ppm) FALSE 1606 4 1 Nickel (Ni) 14 parts per million (dry ) (ppm) FALSE 1606 4 1 Selenium (Se) parts per million (dry ) (ppm) TRUE 4 1606 5 1 Arsenic (As) 5 parts per million (dry ) (ppm) FALSE 1606 5 1 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 5 1 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 5 1 Chromium (Cr) 8 parts per million (dry ) (ppm) FALSE 1606 5 1 Lead (Pb) parts per million (dry ) (ppm) TRUE 4 1606 5 1 Manganese (Mn) 28 parts per million (dry ) (ppm) FALSE 1606 5 1 Mercury (Hg) 0.055 parts per million (dry ) (ppm) FALSE 1606 5 1 Nickel (Ni) 8 parts per million (dry ) (ppm) FALSE 1606 5 1 Selenium (Se) parts per million (dry ) (ppm) TRUE 4

Page 69test_reports

facility _id report_id report_ty pe other_ty pe report_description report_begin_date

report_end_date

before_control

during_deviation 1606 Hg CEM certification 2008

compliance as above ######## ######## No No 1606 Hg CEMS certification 2009

compliance as above 12/7/2009 ######## No No 1606 Hg emissions 2006

other company

initiated ######## No No 1606 Hg emissions Jan. 2007

compliance 1/23/2007 1/25/2007 No No 1606 Hg emissions Sept 2007

compliance 9/5/2007 No No 1606 Jan 2008 initial Hg CEMS certification

compliance as above 1/24/2008 2/5/2008 No No 1606 Oct 2006 compliance

compliance ######## ######## No No 1606 Turbosorp - initial compliance test

compliance dem onstration of control efficiencies and compliance with emission limits ######## No No

Page 70test_reports

deviation_reports No No No No No No No No

Page 71test_report_configurations

facility _id report_id configuration_id 1606 Hg CEM certification 2008

1 current 1606 Hg CEMS certification 2009

1 current 1606 Hg emissions Sept 2007

1 current 1606 Jan 2008 initial Hg CEMS certification

1 current 1606 Turbosorp - initial compliance test

1 current

Page 72test_report_fuels

facility _id report_id fuel_id 1606 Hg CEM certification 2008

coal 1606 Hg CEMS certification 2009

coal 1606 Hg emissions 2006

coal 1606 Hg emissions Jan. 2007

coal 1606 Hg emissions Sept 2007

coal 1606 Jan 2008 initial Hg CEMS certification

coal 1606 Oct 2006 compliance

coal 1606 Turbosorp - initial compliance test

coal

Page 73test_report_fuel_ty pes

facility _id report_id fuel_id fuel_ty pe percentage_massvol percentage_btu

other_ty pe 1606 Hg CEM certification 2008

coal coal - bituminous 100 100 1606 Hg CEMS certification 2009

coal coal - bituminous 100 100 1606 Hg emissions 2006

coal coal - bituminous 100 100 1606 Hg emissions Jan. 2007

coal coal - bituminous 100 100 1606 Hg emissions Sept 2007

coal coal - bituminous 100 100 1606 Jan 2008 initial Hg CEMS certification

coal coal - bituminous 100 100 1606 Oct 2006 compliance

coal coal - bituminous 100 100 1606 Turbosorp - initial compliance test

coal coal - bituminous 100 100

Page 74cem_data

facility _id tim e_period

cem_period_description 1606 01/25/2008 to present

Hg CEM certified Jan. 2008 as required by Mass. DEP

Page 75cem_data_pollutants1

facility _id tim e_period

pollutant_nam e 1606 01/25/2008 to present

Total Mercury

(Hgt)

Page 76test_report_sampling

facility _id report_id sampling_port_id point_differ point_description befre_SO2_device

point_orientation

normal_by pass_percent

testing_by pass_percent 1606 Hg CEM certification 2008

STK1 No No 1606 Hg CEMS certification 2009

STK1 No No 1606 Hg emissions 2006

STK1 No No 1606 Hg emissions Jan. 2007

STK1 No No 1606 Hg emissions Sept 2007

STK1 No No 1606 Jan 2008 initial Hg CEMS certification

STK1 No No 1606 Oct 2006 compliance

STK1 No No 1606 Turbosorp - initial compliance test

STK1 No No

Page 77test_report_sampling

fg_fraction

Page 78sampling_runs

facility _id report_id sampling_port_id run_id start_datetime end_datetim e

unit_load net_generation fg_moisture_content 1606 Hg CEM certification 2008

STK1 average ######## ######## 149 139 1606 Hg CEMS certification 2009

STK1 average 12/7/2009 ######## 148 135 1606 Hg emissions 2006

STK1 average ######## ######## 1606 Hg emissions Jan. 2007

STK1 average 1/23/2007 1/25/2007 150 1606 Hg emissions Sept 2007

STK1 average 9/5/2007 9/5/2007 1606 Jan 2008 initial Hg CEMS certification

STK1 average 1/24/2008 2/5/2008 149 139 6.3 1606 Oct 2006 compliance

STK1 average ######## ######## 145 135 7.5 1606 Turbosorp - initial compliance test

STK1 1 1/20/2009 1/20/2009 155 143 1606 Turbosorp - initial compliance test

STK1 2 1/20/2009 1/20/2009 155 143 1606 Turbosorp - initial compliance test

STK1 3 1/19/2009 1/19/2009 155 143 1606 Turbosorp - initial compliance test

STK1 4 1/20/2009 1/20/2009 155 143

Page 79sampling_runs

fg_flow_rate

fg_flow_rate_units

standard_temperature

standard_pressure

normal_temperature

normal_pressure

fg_oxygen_content

fg_CO2_content

fg_temperature 68 29.92 68 29.92
68 29.92 444000 dscfm 68 29.92 7.7 11.8 298 7.73 11.79 7.684 11.818

11.941 11.701

Page 80sampling_runs

fg_pressure

Hg_loi test_method run_comments

fuel_id fuel_unit_load fuel_flow_rate

fuel_ash fuel_heating_value

30.03 coal 155 8.95 13266 coal 155 8.6 13366

Page 81sampling_runs

fuel_sulfur

1.16 1.58

Page 82sampling_run_pollutants1

facility _id report_id sampling_port_id run_id pollutant_nam e conc conc_units conc_ND conc_MDL 1606 Hg emissions 2006

STK1 average Total Mercury (Hgt) 1.92 mi crogram per dry standard cubic meter ( FALSE 1606 Hg emissions Jan. 2007

STK1 average Total Mercury (Hgt) 1.796 mi crogram per dry standard cubic meter ( FALSE 1606 Hg emissions Sept 2007

STK1 average Total Mercury (Hgt) 2.407 mi crogram per dry standard cubic meter ( FALSE 1606 Hg emissions Sept 2007

STK1 average Particulate-bound Mercury (Hgp) 0.03 mi crogram per dry standard cubic meter ( FALSE 1606 Jan 2008 initial Hg CEMS certification

STK1 average Total Mercury (Hgt) 1.43 mi crogram per dry standard cubic meter ( FALSE 1606 Hg CEM certification 2008

STK1 average Total Mercury (Hgt) 1.829 mi crogram per dry standard cubic meter ( FALSE 1606 Hg CEMS certification 2009

STK1 average Total Mercury (Hgt) 0.17 mi crogram per dry standard cubic meter ( FALSE 1606 Turbosorp - initial compliance test

STK1 1 Total Suspended Particulates (TSP) FALSE 1606 Turbosorp - initial compliance test

STK1 1 PM (Filterable) FALSE 1606 Turbosorp - initial compliance test

STK1 1 PM (Condensable) FALSE 1606 Turbosorp - initial compliance test

STK1 2 Sulfur Dioxide (SO2) 26.08 parts per million by volum e (dry ) (ppmvd) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Total Mercury (Hgt) 0.096 mi crogram per dry standard cubic meter ( FALSE 1606 Turbosorp - initial compliance test

STK1 4 Total Mercury (Hgt) 0.022 mi crogram per dry standard cubic meter ( FALSE 1606 Oct 2006 compliance

STK1 average PM (Filterable) FALSE 1606 Oct 2006 compliance

STK1 average PM (Condensable) FALSE 1606 Oct 2006 compliance

STK1 average Nitrogen Oxide (NOx) FALSE 1606 Oct 2006 compliance

STK1 average Sulfur Dioxide (SO2) FALSE 1606 Oct 2006 compliance

STK1 average Carbon Monoxide (CO) 150 parts per million by volum e (dry ) (ppmvd) FALSE

Page 83sampling_run_pollutants1

em ission_rate

em ission_rate_units

em ission_rate_ND

em ission_rate_MDL

em ission_factor

em ission_factor_units

em ission_factor_ND

em ission_factor_MDL

run_pollutant_comment FALSE 1.86 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 1.726 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 2.247 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE 0.025 pound per trillion British Thermal Unit (lb/1012Btu) FALSE FALSE FALSE FALSE FALSE FALSE FALSE FALSE 0.0059 pound per million British Thermal Unit (lb/MMBtu) FALSE 3 run average on Jan. 20, 2010, measured in stack FALSE 0.0055 pound per million British Thermal Unit (lb/MMBtu) FALSE 3 run average, measured in stack, January 20, 2010 FALSE 0.0004 pound per million British Thermal Unit (lb/MMBtu) FALSE 3 run average, measured in stack, Jan. 20, 2010 FALSE 0.066 pound per million British Thermal Unit (lb/MMBtu) FALSE me asured in stack, average of 3 runs on Jan. 20, 2010 FALSE 0.09 pound per trillion British Thermal Unit (lb/1012Btu) FALSE average of 3 runs on Jan. 19, 2010, measured in stack, W ITHOUT PAC injection FALSE 0.021 pound per trillion British Thermal Unit (lb/1012Btu) FALSE average of 3 runs, Jan. 20, 2010, measured in stack, W ITH PAC injection 14.6 pound per hour (lb/hr)

FALSE FALSE 20.4 pound per hour (lb/hr)

FALSE FALSE FALSE 0.08 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE 0.758 pound per million British Thermal Unit (lb/MMBtu) FALSE FALSE FALSE at 3% O2

Page 84sampling_run_pollutants1 run_pollutant_comment

3 run average on Jan. 20, 2010, measured in stack 3 run average, measured in stack, January 20, 2010 3 run average, measured in stack, Jan. 20, 2010 me asured in stack, average of 3 runs on Jan. 20, 2010 average of 3 runs on Jan. 19, 2010, measured in stack, W ITHOUT PAC injection average of 3 runs, Jan. 20, 2010, measured in stack, W ITH PAC injection

Page 85sampling_run_fuel

facility _id report_id sampling_port_id run_id fuel_pollutant fuel_conc fuel_conc_units fuel_conc_ND

fuel_conc_MDL 1606 Turbosorp - initial compliance test

STK1 3 Antim ony (Sb) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Arsenic (As) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Barium (Ba) 42 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Chloride (Cl) 300 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Chromium (Cr) 11 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Cobalt (Co) 3 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Copper (Cu) 8 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Lead (Pb) 5 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Manganese (Mn) 23 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Mercury (Hg) 0.06 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Moly bdenum (Mo) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Nickel (Ni) 10 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 3 Selenium (Se) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 3 Vanadium (V) 25 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Antim ony (Sb) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Arsenic (As) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Barium (Ba) 34 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Bery llium (Be) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Cadmium (Cd) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Chloride (Cl) 400 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Chromium (Cr) 11 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Cobalt (Co) 3 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Copper (Cu) 7 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Lead (Pb) 6 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Manganese (Mn) 26 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Mercury (Hg) 0.08 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Moly bdenum (Mo) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Nickel (Ni) 8 parts per million (dry ) (ppm) FALSE 1606 Turbosorp - initial compliance test

STK1 4 Selenium (Se) parts per million (dry ) (ppm) TRUE 2 1606 Turbosorp - initial compliance test

STK1 4 Vanadium (V) 24 parts per million (dry ) (ppm) FALSE

Page 86sampling_run_fuel fuel_conc_MDL

Page 87