Subpart Q consists of facilities with any of the following processes: taconite iron ore processing, integrated iron and steel manufacturing, coke making not collocated with an integrated iron and steel manufacturing process, direct reduction not collocated with an integrated iron and steel manufacturing process and electric arc furnace (EAF) steelmaking not collocated with an integrated iron and steel manufacturing process. Note for by-product recovery coke oven battery combustion stacks, blast furnace stoves, boilers, process heaters, reheat furnaces, annealing furnaces, flame suppression, ladle reheaters, and other miscellaneous combustion sources you should review the reporting instructions for Subpart C.

This page provides an overview of subtopics that are central to Subpart Q reporting. This information is entered from the Cal e-GGRT Subpart Q Overview web form shown below. Each topic represents a key web form(s) where you need to enter information:

• #Subpart Q Unit Information
• #Subpart Q Emissions Information
• #Subpart Q Coke Pushing Operation Information
• #Subpart Q Flares Information
• #Subpart Q Validation Report

The end of the page provides links you can use for more detailed information and instructions on entering required information related to each of these topics.

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Subpart Q Unit Information

The required process unit information and the forms associated with required unit information entered into Cal e-GGRT are different for units that are monitored by a Continuous Emissions Monitoring System (CEMS) and units that are NOT monitored by CEMS.

As a result, separate help content has been created in this subpart for entering process unit information for units monitored by CEMS and units NOT monitored by CEMS.

For each process unit that is NOT monitored by CEMS at your facility, the following unit information is required:

• An indication of the calculation methodology used to estimate quantities of CO₂ for this unit (Carbon mass balance method or Site-specific emission factor method)
• A unique name or identifier, plus optional description for this process unit
• The type of process unit
• The name and type of each input and output associated with the process unit (Note: This requirement applies only if carbon mass balance method is used to estimate CO₂ process emissions for the unit. If you have a process input or output other than CO₂ in the exhaust gas that contains carbon that is not included in Equations Q–1 through Q–7 of this section, you must account for the carbon and mass rate of that process input or output in your calculations according to the procedures in §98.174(b)(5). See also the exception in 98.174(b)(4).)

For each process unit that is monitored by CEMS at your facility, the following unit information is required:

• A unique name or identifier for the process unit, plus optional description of the unit
• The type of process unit, selected from the following:
  • Taconite indurating furnace
  • Basic oxygen process furnace
  • Non-recovery coke oven battery
  • Sinter process
  • Electric arc furnace (EAF)
  • Decarburization vessel (see note below)
  • Direct reduction furnace
• Annual production of taconite pellets (metric tons)
• Annual production of molten steel (metric tons)
• Annual production of coke (metric tons)
• Annual production of sinter (metric tons)
• Annual production of direct reduced iron (metric tons)

Subpart Q Coke Pushing Operations Information

For each coke pushing operation at your facility, the following information is required:

• A unique name or identifier, plus optional description

Subpart Q Flares Information

For each flare at your facility, the following information is required:

• A unique name or identifier, plus optional description
• The type of flare
• The flare service type
• The method used to calculate the CO₂ emissions

Subpart Q Emissions Information

The required emissions information and the manner by which required emissions information is entered into Cal e-GGRT is different for process units that are monitored by a Continuous Emissions Monitoring System (CEMS), process units that are NOT monitored by a CEMS, coke pushing operations, and flares.

As a result, separate help content has been created in this subpart for entering emissions information for each emissions source type.

For each process unit that is NOT monitored by CEMS at your facility, the following information is required:

• The annual CO₂ process emissions (e.g. the results from Equation Q-1, in metric tons)
• For each input and output assigned to a process unit for which emissions will be estimated using the carbon mass balance method, also enter the following substitute data information:
  • The annual mass or volume is based on one or more substitute monthly data values
  • The number of months that missing data procedures were followed, if applicable (If not applicable, you must enter zero to avoid data completeness validation error messages on the validation report)
  • The method used to develop the substitute data value(s), if applicable
  • The carbon content determination method

For each CEMS Monitoring Location, provide the following information:

• A unique unit name or identifier for the CML (see also About Unique Unit Names)
• An optional description or label for the CML
• The configuration of processes or process units that are monitored by the CML:
  • Single industrial process or process unit that exhausts to a dedicated stack
  • Multiple industrial processes or process units share a common stack
  • Industrial process or process unit shares a common stack with one or more stationary fuel combustion units
• The name of each fuel combusted in the unit(s) monitored by the CEMS
• The Tier 4/CEMS methodology start and end dates
• The cumulative total of hourly CO₂ mass emissions for each quarter of the reporting year (in metric tons) (Do not cumulate emissions data between quarters)
• The total annual CO2 mass emissions measured by the CEMS (in metric tons)
• An indication whether emissions reported for the CEMS include emissions calculated according to 98.33(a)(4)(viii) for a slipstream that bypassed the CEMS
• The total annual biogenic CO₂ emissions from the combustion of all biomass fuels combined (in metric tons) (if applicable)
• The total annual non-biogenic CO₂ emissions (includes fossil fuel, sorbent, and process CO₂ emissions, in metric tons)
• The total annual CH₄ and N₂O emissions associated with the combustion of all Table C-2 fuels combusted in all processes/process units monitored by the CEMS derived from application of Equation C-10 (in metric tons) (if there are no combustion emissions in this CML, please enter zero)
• The total number of source operating hours in the reporting year
• The total operating hours in which a substitute data value was used in the emissions calculations for the CO₂ concentration parameter
• The total operating hours in which a substitute data value was used in the emissions calculations for the stack gas flow rate parameter
• If moisture correction is required and a continuous moisture monitor is used, the total operating hours in which a substitute data value was used in the emissions calculations for the stack gas moisture content parameter
• An indication of the process units monitored by the CML

For each coke pushing operation at your facility, the following information is required:

• The annual CO₂ process emissions (in metric tons) [See 98.176(c)]

For each flare at your facility, the following information is required:

• The annual CO₂ emissions from flare unit operations (the output of Equation Y-1a, Y-1b, Y-2, or Y-3 depending on the calculation method used for this flare, in metric tons) [98.256(e)(4)]
• The annual CH₄ emissions from flare unit operations (the output of Equation C-9a, in metric tons) [98.33(c)(2) as required by 98.172(b)]
• The annual N₂O emissions from flare unit operations (the output of Equation C-9a, in metric tons) [98.33(c)(2) as required by 98.172(b)]

For each flare using the Equation Y-1a calculation method, Subpart Q requires you to enter the following supplemental emissions information:

• An indication of whether daily or weekly measurement periods are used [98.256(e)(6)]
• The annual volume of flare gas combusted (in scf) [98.256(e)(6)]
• The specific consensus-based standard method number or description of the procedure specified by the flow meter manufacturer [98.256(q)]
• The number of days during the reporting year missing data procedures were used to determine the volume of flare gas combusted
• The annual average molecular weight (in kg/kg-mole) [98.256(e)(6)]
• The method used to measure molecular weight [98.256(q)]
  • Method 18 at 50 CFR part 60, appendix A-6
  • ASTM D1945-03
  • ASTM D1946-90 (Reapproved 2006)
  • GPA 2261-00
  • UOP539-97
  • ASTM D2503-92 (Reapproved 2007)
  • Chromatographic analysis: manufacturer's instructions
• The number of days during the reporting year missing data procedures were used to determine molecular weight
• The annual average carbon content of the flare gas (kg carbon/kg flare gas) [98.256(e)(6)]
• The method used to measure carbon content [98.256(q)]
  • Method 18 at 50 CFR part 60, appendix A-6
  • ASTM D1945-03
  • ASTM D1946-90 (Reapproved 2006)
  • GPA 2261-00
  • UOP539-97
  • ASTM D2503-92 (Reapproved 2007)
  • Chromatographic analysis: manufacturer's instructions
• The number of days during the reporting year missing data procedures were used to determine carbon content

For each flare using the Equation Y-1b calculation method, Subpart Q requires you to enter the following supplemental emissions information:

• An indication of whether daily or weekly measurement periods are used [98.256(e)(7)]
• The annual volume of flare gas combusted (in scf) [98.256(e)(7)]
• The specific consensus-based standard method number or description of the procedure specified by the flow meter manufacturer [98.256(q)]
• The number of days during the reporting year missing data procedures were used to determine the volume of flare gas combusted
• The annual average CO₂ concentration (in percent by volume or mole) [98.256(e)(7)]
• The method used to measure CO₂ concentration [98.256(q)]
  • Method 18 at 50 CFR part 60, appendix A-6
  • ASTM D1945-03
  • ASTM D1946-90 (Reapproved 2006)
  • GPA 2261-00
  • UOP539-97
  • ASTM D2503-92 (Reapproved 2007)
  • Chromatographic analysis: manufacturer's instructions
• The number of days during the reporting year missing data procedures were used to determine CO₂ concentration
• For each carbon containing compound other than CO₂ in the flare gas stream identified by the facility, and for each flare using the Equation Y-1b, the system shall require the facility to identify:
• The annual average concentration of the compound (in percent by volume or mole) [98.256(e)(7)(i)]
• The method used to measure concentration of the compound [98.256(q)]
  • Method 18 at 50 CFR part 60, appendix A-6
  • ASTM D1945-03
  • ASTM D1946-90 (Reapproved 2006)
  • GPA 2261-00
  • UOP539-97
  • ASTM D2503-92 (Reapproved 2007)
  • Chromatographic analysis: manufacturer's instructions
• The number of days during the reporting year missing data procedures were used to determine the concentration of the compound

For each flare using the Equation Y-2 calculation method, Subpart Q requires you to enter the following supplemental emissions information:

• An indication of whether daily or weekly measurement periods are used [98.256(e)(8)]
• The annual volume of flare gas combusted (in MMscf) [98.256(e)(8)]
• The specific consensus-based standard method number or description of the procedure specified by the flow meter manufacturer [98.256(q)]
• The number of days during the reporting year missing data procedures were used to determine the volume of flare gas combusted
• The annual average higher heating value of the flare gas (MMBtu/MMscf) [98.256(e)(8)]
• The method used to measure higher heating value of the flare gas [98.256(q)]
  • ASTM D4809-06
  • ASTM D240-02 (Reapproved 2007)
  • ASTM D1826-94 (Reapproved 2003)
  • ASTM D3588-98 (Reapproved 2003)
  • ASTM D4891-89 (Reapproved 2006)
  • Chromatographic analysis: manufacturer's instructions
• The number of days during the reporting year missing data procedures were used to determine the higher heating value of the flare gas
• An indication of whether the annual volume of flare gas combusted was determined using standard conditions of 68 ºF and 14.7 psia or 60 ºF and 14.7 psia [98.256(e)(8)]
• An indication of whether the annual average higher heating value of the flare gas was determined using standard conditions of 68 ºF and 14.7 psia or 60 ºF and 14.7 psia [98.256(e)(8)]

For each flare using the Equation Y-3 calculation method, Subpart Q requires you to enter the following supplemental emissions information:

• The total number of start-up, shutdown, or malfunction (SSM) events exceeding 500,000 scf/day [98.256(e)(9)]

Subpart Q Validation Report

You can use the Validation Report to ensure the completeness and quality of your reporting data.

You should use the Validation Report to check your work. The Validation Report performs two types of checks:

• Data Completeness: Data that are required for reporting is missing or incomplete.
• Data Quality: Data are outside of the expected range of values.

You may view the Validation Report at any time.

Note that the Validation Report is intended to assist users in entering data, but it is not an indication that the reporter has entered all necessary information, nor is it an indication that the reporter is in compliance with 40 CFR Part 98. Furthermore a negative finding on the validation report is not a guarantee that a data element was entered incorrectly.

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See Also

Screen Errors
Using Cal e-GGRT to Prepare Your Subpart Q Report
Subpart Q Process Unit Information for Units NOT Monitored by CEMS
Subpart Q Process Unit Information for Units Monitored by CEMS
Subpart Q Coke Pushing Operations Information
Subpart Q Flares Information
Subpart Q Emissions Information for Units NOT Monitored by CEMS
Subpart Q Emissions Information for Units Monitored by CEMS
Subpart Q Emissions Information for Coke Pushing Operations
Subpart Q Emissions Information for Flares
Subpart Validation Report