Subpart C. General Stationary Fuel Combustion Sources

• Q44. There is currently no CEMS available at my facility. Is there a provision to allow calculations of Tier 1, 2 or 3 if the cost of purchasing and installing CEMS will be seriously detrimental to the company?
• Q64. Should pilot light emissions be included in greenhouse gas emissions reported in subpart C of Part 98?
• Q66. Where does no. 2 diesel fuel fit into Table C-1 and C-2?
• Q67. Where the heat input capacity of a combustion unit is less than 250 mmBtu per hour input capacity and the unit is not subject to Tier 3 or 4 per Subpart Y of Part 98, and where there might be more than one fuel type fed to...?
• Q69. Does fuel use for comfort heating and hot water heaters need to be reported?
• Q68. 40 CFR §98.33(a)(3)(iii) indicates that "For units that combust municipal solid waste (MSW) and that produce steam, use Equation C-2c of this section". However, Table C-1...
• Q70. Would fuels combusted in a test stand be considered as stationary fuel combustion when the articles being tested are mobile sources (aircraft, rocket, missile, spacecraft)?
• Q73. If a non-Acid Rain unit combusts coal or other solid fossil fuel and has gas monitors installed but does not have a stack flow monitor, is installation and certification of a stack flow monitor required?
• Q74. If a unit that combusts only fossil fuels has a CEMS for CO2 and uses Tier 4, must CO2 be reported by fuel type?
• Q75. For a unit that combusts fossil and biomass fuels that has a CEMS for CO2 and uses Tier 4, must CO2 be reported by fuel type?
• Q76. For a group of units that combusts only pipeline quality natural gas, may a shared fuel flow meter on a common pipe or gas supplier billing meter data be used to determine the CO2 mass emissions for the group of units?
• Q77. For a unit that has an O2 monitor and doesn't meet the conditions required to use Tier 4, but elects to use Tier 4, what are the monitoring requirements?
• Q80. If the HHV is known as part of a general energy management system, but not sampled on a routine basis, may Tier 1 be used?
• Q81. If a combustion unit is greater than 250 mmBtu per hour, combusts a biomass fuel listed in Table C-1, and receives HHV data at the required frequency in §98.34(a), may Tier 1 be used per 40 CFR 98.33(b)(1)(iii)?
• Q82. For a combustion turbine that only burns diesel oil and pipeline natural gas, is it acceptable to use Tier 2 to calculate CO2 emissions?
• Q83. For diesel fuel (e.g., No. 1 or No. 2 fuel oil) shipments that are received 1 or 2 times a year, is it sufficient to sample the fuel carbon content upon receipt of each shipment for Tier 3?
• Q84. For a unit that is not required to use Tier 4 (CEMS monitoring), which tier is required if you receive HHV with some coal shipments, but not every coal shipment?
• Q85. Is the use of Subpart C tiers required after 2010 and is it acceptable to use the best available monitoring provisions under Subpart A beyond 2010?
• Q86. Does Tier 3 have to be used if a unit is less than or equal to 250 mmBtu per hour, but has a continuous gas chromatograph to determine carbon content?
• Q87. What Tier, if any, must be used for a fuel not listed in Table C-1 that is less than 10% of the heat input of a combustion unit?
• Q88. If a combustion unit with a heat input capacity less than 250 mmBtu per hour burns both natural gas and a liquid fuel, and the quantities are known...
• Q90. Does EPA accept thermal flow meters for measuring volumetric flow rate under 98.34?
• Q91. Are orifice, venturi, and nozzle flow meters required to have temperature and total pressure transmitters located on the flowmeters?
• Q93. What should facilities do if the calibration error for fuel flow meters that exceeds the 5.0% performance specification?
• Q95. If a facility has a billing meter for natural gas for units throughout the facility and individual units also have their own meters, is there an obligation under the rule to use the individual unit meters?
• Q96. Is there a recurring fuel flow meter calibration requirement for Tier 1 and Tier 2 units?
• Q97. Does the calibration exemption for fuel billing meters still apply for common pipe reporting option?
• Q133. Can I use more than 1 Tier Method for my facility?
• Q134. I have a natural gas emergency generator and a boiler in a building within the facility but no means to separate the usage out - how do I account for that, since the e-gen is not included?
• Q135. I have natural gas meter records for a building that uses natural gas for heating and cooking - but no separate meters - how do we account for that?
• Q138. Please explain what High Heat Value (HHV) testing is and how a school's EH&S personnel would know if this is occurring?
• Q139. Would a boiler (or other combustion unit) that is mounted on a trailer or movable platform, that is used to provide temporary services while facility equipment is serviced, upgraded, or replaced, and where such equipment remains at the facility...
• Q137. I do not have a fuel meter on the source at a building, but know how much fuel is delivered. This is not the actual amount used, since my inventory at the beginning of the year may be different than the end - should I use the delivered amount?
• Q140. Would the following be considered stationary or portable sources, assuming their location falls within the definition of facility?
• Q146. Many facilities use mass or volumetric flow meters to measure gaseous streams. Please confirm whether it is acceptable to use a mass flow meter to determine the volumetric flow rate of gaseous streams under Subpart C or the GHG Reporting Rule.
• Q148. With respect to coal or fuel oil, the rule requires analysis of at least one representative sample from each lot. Does EPA have any additional guidance on what constitutes a "lot?"
• Q149. If coal comes from the same source, how many deliveries must be analyzed to have a representative sample?
• Q307. How do you report a unit in e-GGRT that uses Tier 2 or 3 for part of the year and CEMS for the remainder of the year?
• Q308. How do you report in e-GGRT a fuel that changed calculation methodology from Tier 1 to Tier 2 for a given configuration during the middle of the year?
• Q322. To what precision should emission values for CO2, N2O, and CH4 be reported in e-GGRT?
• Q325. What are biogenic emissions?
• Q326. What are non-biogenic CO2 emissions?
• Q327. If multiple subparts apply to our sources such as subparts A, C, and D, are we reporting data under all three subparts?
• Q328. For Tier 4 configurations, if there are no missing data, do you still have to report total operating hours in the reporting year and zeros for hours in which substitute data was use?
• Q329. Is a blend of natural gas and biogas a unique fuel type that must be added?
• Q330. If a natural gas common pipe is connected to a series of small combustion units and a subpart D unit, how should emissions be reported?
• Q331. Am I required to report emissions for emergency generators?
• Q332. Is there a limit on the number of units or fuel types listed for an aggregation of units configuration?
• Q333. Can you change configuration types from year to year?
• Q334. Is there any flexibility in deciding what configuration type I can use for a unit or group of units?
• Q335. Am I required to enter emissions for each fuel type?
• Q337. If a facility is permitted to burn fuel of a certain type but did not burn it during the reporting year, is it required to identify that fuel type in e-GGRT?
• Q338. For Tier 3, if I have multiple combustion sources using a single fuel type, should I enter this as an aggregation of units?
• Q753. How do I use Equation C-2b to calculate the annual average high heating value (HHV) of my fuel if the rule requires sampling less frequently than monthly?
• Q817. Do enclosed flare systems have to report emissions under 40 CFR part 98 subpart C?
• Q851. My aggregation of units/common pipe configuration contains few units with a maximum rated heat input capacity >=10 mmbtu/hr. If I only enter the cumulative maximum rated heat input capacity for those units >=10, I receive a data validation error.