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Subpart DDDDD - National Emission Standards for Hazardous Air Pollutants for Major Sources Industrial, Commercial, and Institutional Boilers and Process Heaters

RegSenseCFR SubpartCFR RegulationsEnvironmental Protection Agency (EPA)Hazardous Air PollutantsEnvironmentalAir QualityFocus AreaEnglishAir ProgramsUSA

Table 1 to Subpart DDDDD of Part 63—Emission Limits for New or Reconstructed Boilers and Process Heaters c

[As stated in §63.7500, you must comply with the following applicable emission limits: [Units with heat input capacity of 10 million Btu per hour or greater]

Table 2 to Subpart DDDDD of Part 63—Emission Limits for Existing Boilers and Process Heaters d

Table 2 to Subpart DDDDD of Part 63—Emission Limits for Existing Boilers and Process Heaters d[As stated in §63.7500, you must comply with the following applicable emission limits: [Units with heat input capacity of 10 million Btu per hour or greater]
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during startup and shutdown . . . The emissions must not exceed the following alternative output-based limits, except during startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit, you can skip testing according to §63.7515 if all of the other provisions of §63.7515 are met. For all other pollutants that do not contain a footnote a, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c An owner or operator may determine compliance with the carbon monoxide emissions limit be determined using CO 2 as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit and must also take into account that the 3-percent oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
d Before October 6, 2025 you may comply with the emission limits in Table 15 to this subpart. On and after October 6, 2025], you must comply with the emission limits in this Table 2.
1. Units in all subcategories designed to burn solid fuel a. HCl 2.0E-02 lb per MMBtu of heat input 2.3E-02 lb per MMBtu of steam output or 0.26 lb per MWh For M26A, collect a minimum of 1 dscm per run; for M26, collect a minimum of 120 liters per run.
b. Mercury 5.4E-06 lb per MMBtu of heat input 6.2E-06 lb per MMBtu of steam output or 6.9E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
2. Units design to burn coal/solid fossil fuel a. Filterable PM (or TSM) 3.9E-02 lb per MMBtu of heat input; or (5.3E-05 lb per MMBtu of heat input) 4.1E-02 lb per MMBtu of steam output or 4.8E-01 lb per MWh; or (5.6E-05 lb per MMBtu of steam output or 6.5E-04 lb per MWh) Collect a minimum of 2 dscm per run.
3. Pulverized coal boilers designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 0.11 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
4. Stokers/others designed to burn coal/solid fossil fuel a. CO (or CEMS) 150 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 0.14 lb per MMBtu of steam output or 1.6 lb per MWh; 3-run average 1 hr minimum sampling time.
5. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 0.12 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
6. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 1.3E-01 lb per MMBtu of steam output or 1.5 lb per MWh; 3-run average 1 hr minimum sampling time.
7. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 1,100 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (720 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 1.1 lb per MMBtu of steam output or 13 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.4E-02 lb per MMBtu of heat input; or (2.0E-04 lb per MMBtu of heat input) 4.0E-02 lb per MMBtu of steam output or 4.8E-01 lb per MWh; or (2.4E-04 lb per MMBtu of steam output or 2.8E-03 lb per MWh) Collect a minimum of 2 dscm per run.
8. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 460 ppm by volume on a dry basis corrected to 3-percent oxygen 4.2E-01 lb per MMBtu of steam output or 5.1 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.2E-01 lb per MMBtu of heat input; or (5.0E-03 lb per MMBtu of heat input) 3.7E-01 lb per MMBtu of steam output or 4.5 lb per MWh; or (5.9E-03 lb per MMBtu of steam output or 7.0E-02 lb per MWh) Collect a minimum of 1 dscm per run.
9. Fluidized bed units designed to burn biomass/bio-based solid a. CO (or CEMS) 210 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 2.1E-01 lb per MMBtu of steam output or 2.3 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 7.4E-03 lb per MMBtu of heat input; or (6.4E-05 lb per MMBtu of heat input) 9.2E-03 lb per MMBtu of steam output or 0.11 lb per MWh; or (8.0E-05 lb per MMBtu of steam output or 9.0E-04 lb per MWh) Collect a minimum of 1 dscm per run.
10. Suspension burners designed to burn biomass/bio-based solid a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3-percent oxygen, c 10-day rolling average) 1.9 lb per MMBtu of steam output or 27 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 4.1E-02 lb per MMBtu of heat input; or (8.0E-03 lb per MMBtu of heat input) 4.2E-02 lb per MMBtu of steam output or 5.8E-01 lb per MWh; or (8.1E-03 lb per MMBtu of steam output or 0.12 lb per MWh) Collect a minimum of 2 dscm per run.
11. Dutch Ovens/Pile burners designed to burn biomass/bio-based solid a. CO (or CEMS) 770 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3-percent oxygen, c 10-day rolling average) 8.4E-01 lb per MMBtu of steam output or 8.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.8E-01 lb per MMBtu of heat input; or (2.0E-03 lb per MMBtu of heat input) 2.5E-01 lb per MMBtu of steam output or 2.6 lb per MWh; or (2.8E-03 lb per MMBtu of steam output or 2.8E-02 lb per MWh) Collect a minimum of 1 dscm per run.
12. Fuel cell units designed to burn biomass/bio-based solid a. CO 1,100 ppm by volume on a dry basis corrected to 3-percent oxygen 2.4 lb per MMBtu of steam output or 12 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (5.8E-03 lb per MMBtu of heat input) 5.5E-02 lb per MMBtu of steam output or 2.8E-01 lb per MWh; or (1.6E-02 lb per MMBtu of steam output or 8.1E-02 lb per MWh) Collect a minimum of 2 dscm per run.
13. Hybrid suspension grate units designed to burn biomass/bio-based solid a. CO (or CEMS) 3,500 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 3.5 lb per MMBtu of steam output or 39 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 4.4E-01 lb per MMBtu of heat input; or (4.5E-04 lb per MMBtu of heat input) 5.5E-01 lb per MMBtu of steam output or 6.2 lb per MWh; or (5.7E-04 lb per MMBtu of steam output or 6.3E-03 lb per MWh) Collect a minimum of 1 dscm per run.
14. Units designed to burn liquid fuel a. HCl 1.1E-03 lb per MMBtu of heat input 1.4E-03 lb per MMBtu of steam output or 1.6E-02 lb per MWh For M26A, collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
b. Mercury 7.3E-07 lb per MMBtu of heat input 8.8E-07 lb per MMBtu of steam output or 1.1E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B collect a minimum sample as specified in the method, for ASTM D6784 b collect a minimum of 2 dscm.
15. Units designed to burn heavy liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 5.9E-02 lb per MMBtu of heat input; or (2.0E-04 lb per MMBtu of heat input) 7.2E-02 lb per MMBtu of steam output or 8.2E-01 lb per MWh; or (2.5E-04 lb per MMBtu of steam output or 2.8E-03 lb per MWh) Collect a minimum of 1 dscm per run.
16. Units designed to burn light liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.13 lb per MMBtu of steam output or 1.4 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 7.9E-03 lb per MMBtu of heat input; or (6.2E-05 lb per MMBtu of heat input) 9.6E-03 lb per MMBtu of steam output or 1.1E-01 lb per MWh; or (7.5E-05 lb per MMBtu of steam output or 8.6E-04 lb per MWh) Collect a minimum of 3 dscm per run.
17. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average based on stack test 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.2E-01 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) 2.7E-01 lb per MMBtu of steam output or 3.1 lb per MWh; or (1.1E-03 lb per MMBtu of steam output or 1.2E-02 lb per MWh) Collect a minimum of 2 dscm per run.
18. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.16 lb per MMBtu of steam output or 1.0 lb per MWh 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input 2.9E-03 lb per MMBtu of steam output or 1.8E-02 lb per MWh For M26A, collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input 1.4E-05 lb per MMBtu of steam output or 8.3E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 2 dscm.
d. Filterable PM (or TSM) 7.3E-03 lb per MMBtu of heat input or (2.1E-04 lb per MMBtu of heat input) 1.3E-02 lb per MMBtu of steam output or 7.6E-02 lb per MWh; or (3.5E-04 lb per MMBtu of steam output or 2.2E-03 lb per MWh) Collect a minimum of 3 dscm per run.

[78 FR 7195, Jan. 31, 2013, as amended at 80 FR 72821, Nov. 20, 2015; 87 FR 60849, Oct. 6, 2022]

Table 3 to Subpart DDDDD of Part 63 - Work Practice Standards

As stated in §63.7500, you must comply with the following applicable work practice standards:

Table 3 to Subpart DDDDD of Part 63—Work Practice Standards
If your unit is . . . You must meet the following . . .
a As specified in §63.7555(d)(13), the source may request an alternative timeframe with the PM controls requirement to the permitting authority (state, local, or tribal agency) that has been delegated authority for this subpart by EPA. The source must provide evidence that (1) it is unable to safely engage and operate the PM control(s) to meet the “fuel firing 1 hour” requirement and (2) the PM control device is appropriately designed and sized to meet the filterable PM emission limit. It is acknowledged that there may be another control device that has been installed other than ESP that provides additional PM control (e.g., scrubber).
1. A new or existing boiler or process heater with a continuous oxygen trim system that maintains an optimum air to fuel ratio, or a heat input capacity of less than or equal to 5 million Btu per hour in any of the following subcategories: unit designed to burn gas 1; unit designed to burn gas 2 (other); or unit designed to burn light liquid, or a limited use boiler or process heater Conduct a tune-up of the boiler or process heater every 5 years as specified in §63.7540.
2. A new or existing boiler or process heater without a continuous oxygen trim system and with heat input capacity of less than 10 million Btu per hour in the unit designed to burn heavy liquid or unit designed to burn solid fuel subcategories; or a new or existing boiler or process heater with heat input capacity of less than 10 million Btu per hour, but greater than 5 million Btu per hour, in any of the following subcategories: unit designed to burn gas 1; unit designed to burn gas 2 (other); or unit designed to burn light liquid Conduct a tune-up of the boiler or process heater biennially as specified in §63.7540.
3. A new or existing boiler or process heater without a continuous oxygen trim system and with heat input capacity of 10 million Btu per hour or greater Conduct a tune-up of the boiler or process heater annually as specified in §63.7540. Units in either the Gas 1 or Metal Process Furnace subcategories will conduct this tune-up as a work practice for all regulated emissions under this subpart. Units in all other subcategories will conduct this tune-up as a work practice for dioxins/furans.
4. An existing boiler or process heater located at a major source facility, not including limited use units Must have a one-time energy assessment performed by a qualified energy assessor. An energy assessment completed on or after January 1, 2008, that meets or is amended to meet the energy assessment requirements in this table, satisfies the energy assessment requirement. A facility that operated under an energy management program developed according to the ENERGY STAR guidelines for energy management or compatible with ISO 50001 for at least one year between January 1, 2008 and the compliance date specified in §63.7495 that includes the affected units also satisfies the energy assessment requirement. The energy assessment must include the following with extent of the evaluation for items a. to e. appropriate for the on-site technical hours listed in §63.7575:
a. A visual inspection of the boiler or process heater system.
b. An evaluation of operating characteristics of the boiler or process heater systems, specifications of energy using systems, operating and maintenance procedures, and unusual operating constraints.
c. An inventory of major energy use systems consuming energy from affected boilers and process heaters and which are under the control of the boiler/process heater owner/operator.
d. A review of available architectural and engineering plans, facility operation and maintenance procedures and logs, and fuel usage.
e. A review of the facility's energy management program and provide recommendations for improvements consistent with the definition of energy management program, if identified.
f. A list of cost-effective energy conservation measures that are within the facility's control.
g. A list of the energy savings potential of the energy conservation measures identified.
h. A comprehensive report detailing the ways to improve efficiency, the cost of specific improvements, benefits, and the time frame for recouping those investments.
5. An existing or new boiler or process heater subject to emission limits in Table 1 or 2 or 11 through 15 to this subpart during startup a. You must operate all CMS during startup. b. For startup of a boiler or process heater, you must use one or a combination of the following clean fuels: natural gas, synthetic natural gas, propane, other Gas 1 fuels, distillate oil, syngas, ultra-low sulfur diesel, fuel oil-soaked rags, kerosene, hydrogen, paper, cardboard, refinery gas, liquefied petroleum gas, clean dry biomass, and any fuels meeting the appropriate HCl, mercury and TSM emission standards by fuel analysis.
c. You have the option of complying using either of the following work practice standards. (1) If you choose to comply using paragraph (1) of the definition of “startup” in §63.7575, once you start firing fuels that are not clean fuels you must vent emissions to the main stack(s) and engage all of the applicable control devices except limestone injection in fluidized bed combustion (FBC) boilers, dry scrubber, fabric filter, and selective catalytic reduction (SCR). You must start your limestone injection in FBC boilers, dry scrubber, fabric filter, and SCR systems as expeditiously as possible. Startup ends when steam or heat is supplied for any purpose, OR (2) If you choose to comply using paragraph (2) of the definition of “startup” in §63.7575, once you start to feed fuels that are not clean fuels, you must vent emissions to the main stack(s) and engage all of the applicable control devices so as to comply with the emission limits within 4 hours of start of supplying useful thermal energy. You must engage and operate PM control within one hour of first feeding fuels that are not clean fuels a . You must start all applicable control devices as expeditiously as possible, but, in any case, when necessary to comply with other standards applicable to the source by a permit limit or a rule other than this subpart that require operation of the control devices. You must develop and implement a written startup and shutdown plan, as specified in §63.7505(e).
d. You must comply with all applicable emission limits at all times except during startup and shutdown periods at which time you must meet this work practice. You must collect monitoring data during periods of startup, as specified in §63.7535(b). You must keep records during periods of startup. You must provide reports concerning activities and periods of startup, as specified in §63.7555.
6. An existing or new boiler or process heater subject to emission limits in Table 1 or 2 or Tables 11 through 15 to this subpart during shutdown You must operate all CMS during shutdown. While firing fuels that are not clean fuels during shutdown, you must vent emissions to the main stack(s) and operate all applicable control devices, except limestone injection in FBC boilers, dry scrubber, fabric filter, and SCR but, in any case, when necessary to comply with other standards applicable to the source that require operation of the control device.
If, in addition to the fuel used prior to initiation of shutdown, another fuel must be used to support the shutdown process, that additional fuel must be one or a combination of the following clean fuels: Natural gas, synthetic natural gas, propane, other Gas 1 fuels, distillate oil, syngas, ultra-low sulfur diesel, refinery gas, and liquefied petroleum gas.
You must comply with all applicable emissions limits at all times except for startup or shutdown periods conforming with this work practice. You must collect monitoring data during periods of shutdown, as specified in §63.7535(b). You must keep records during periods of shutdown. You must provide reports concerning activities and periods of shutdown, as specified in §63.7555.

[78 FR 7198, Jan. 31, 2013, as amended at 80 FR 72823, Nov. 20, 2015; 87 FR 60852, Oct. 6, 2022]

Table 4 to Subpart DDDDD of Part 63 - Operating Limits for Boilers and Process Heaters

As stated in §63.7500, you must comply with the applicable operating limits:

Table 4 to Subpart DDDDD of Part 63 - Operating Limits for Boilers and Process Heaters
When complying with a numerical emission limit under Table 1, 2, 11, 12, 13, 14, or 15 of this subpart using . . . You must meet these operating limits . . .
a A wet acid gas scrubber is a control device that removes acid gases by contacting the combustion gas with an alkaline slurry or solution. Alkaline reagents include, but not limited to, lime, limestone and sodium.
1. Wet PM scrubber control on a boiler or process heater not using a PM CPMS Maintain the 30-day rolling average pressure drop and the 30-day rolling average liquid flow rate at or above the lowest one-hour average pressure drop and the lowest one-hour average liquid flow rate, respectively, measured during the performance test demonstrating compliance with the PM emission limitation according to §63.7530(b) and Table 7 to this subpart.
2. Wet acid gas (HCl) scrubber a control on a boiler or process heater not using a HCl CEMS Maintain the 30-day rolling average effluent pH at or above the lowest one-hour average pH and the 30-day rolling average liquid flow rate at or above the lowest one-hour average liquid flow rate measured during the performance test demonstrating compliance with the HCl emission limitation according to §63.7530(b) and Table 7 to this subpart.
3. Fabric filter control on a boiler or process heater not using a PM CPMS a. Maintain opacity to less than or equal to 10 percent opacity or the highest hourly average opacity reading measured during the performance test run demonstrating compliance with the PM (or TSM) emission limitation (daily block average); or
b. Install and operate a bag leak detection system according to §63.7525 and operate the fabric filter such that the bag leak detection system alert is not activated more than 5 percent of the operating time during each 6-month period.
4. Electrostatic precipitator control on a boiler or process heater not using a PM CPMS a. This option is for boilers and process heaters that operate dry control systems (i.e., an ESP without a wet scrubber). Existing and new boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity or the highest hourly average opacity reading measured during the performance test run demonstrating compliance with the PM (or TSM) emission limitation (daily block average).
b. This option is only for boilers and process heaters not subject to PM CPMS or continuous compliance with an opacity limit (i.e., dry ESP). Maintain the 30-day rolling average total secondary electric power input of the electrostatic precipitator at or above the operating limits established during the performance test according to §63.7530(b) and Table 7 to this subpart.
5. Dry scrubber or carbon injection control on a boiler or process heater not using a mercury CEMS Maintain the minimum sorbent or carbon injection rate as defined in §63.7575 of this subpart.
6. Any other add-on air pollution control type on a boiler or process heater not using a PM CPMS This option is for boilers and process heaters that operate dry control systems. Existing and new boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity or the highest hourly average opacity reading measured during the performance test run demonstrating compliance with the PM (or TSM) emission limitation (daily block average).
7. Performance testing For boilers and process heaters that demonstrate compliance with a performance test, maintain the 30-day rolling average operating load of each unit such that it does not exceed 110 percent of the highest hourly average operating load recorded during the performance test.
8. Oxygen analyzer system For boilers and process heaters subject to a CO emission limit that demonstrate compliance with an O2 analyzer system as specified in §63.7525(a), maintain the 30-day rolling average oxygen content at or above the lowest hourly average oxygen concentration measured during the CO performance test, as specified in Table 8. This requirement does not apply to units that install an oxygen trim system since these units will set the trim system to the level specified in §63.7525(a).
9. SO2 CEMS For boilers or process heaters subject to an HCl emission limit that demonstrate compliance with an SO2 CEMS, maintain the 30-day rolling average SO2 emission rate at or below the highest hourly average SO2 concentration measured during the HCl performance test, as specified in Table 8.

[80 FR 72874, Nov. 20, 2015]

Table 5 to Subpart DDDDD of Part 63 - Performance Testing Requirements

As stated in §63.7520, you must comply with the following requirements for performance testing for existing, new or reconstructed affected sources:

Table 5 to Subpart DDDDD of Part 63 - Performance Testing Requirements
To conduct a performance test for the following pollutant . . . You must. . . Using, as appropriate . . .
a Incorporated by reference, see §63.14.
1. Filterable PM a. Select sampling ports location and the number of traverse points Method 1 at 40 CFR part 60, appendix A-1 of this chapter.
b. Determine velocity and volumetric flow-rate of the stack gas Method 2, 2F, or 2G at 40 CFR part 60, appendix A-1 or A-2 to part 60 of this chapter.
c. Determine oxygen or carbon dioxide concentration of the stack gas Method 3A or 3B at 40 CFR part 60, appendix A-2 to part 60 of this chapter, or ANSI/ASME PTC 19.10-1981. a
d. Measure the moisture content of the stack gas Method 4 at 40 CFR part 60, appendix A-3 of this chapter.
e. Measure the PM emission concentration Method 5 or 17 (positive pressure fabric filters must use Method 5D) at 40 CFR part 60, appendix A-3 or A-6 of this chapter.
f. Convert emissions concentration to lb per MMBtu emission rates Method 19 F-factor methodology at 40 CFR part 60, appendix A-7 of this chapter.
2. TSM a. Select sampling ports location and the number of traverse points Method 1 at 40 CFR part 60, appendix A-1 of this chapter.
b. Determine velocity and volumetric flow-rate of the stack gas Method 2, 2F, or 2G at 40 CFR part 60, appendix A-1 or A-2 of this chapter.
c. Determine oxygen or carbon dioxide concentration of the stack gas Method 3A or 3B at 40 CFR part 60, appendix A-1 of this chapter, or ANSI/ASME PTC 19.10-1981. a
d. Measure the moisture content of the stack gas Method 4 at 40 CFR part 60, appendix A-3 of this chapter.
e. Measure the TSM emission concentration Method 29 at 40 CFR part 60, appendix A-8 of this chapter
f. Convert emissions concentration to lb per MMBtu emission rates Method 19 F-factor methodology at 40 CFR part 60, appendix A-7 of this chapter.
3. Hydrogen chloride a. Select sampling ports location and the number of traverse points Method 1 at 40 CFR part 60, appendix A-1 of this chapter.
b. Determine velocity and volumetric flow-rate of the stack gas Method 2, 2F, or 2G at 40 CFR part 60, appendix A-2 of this chapter.
c. Determine oxygen or carbon dioxide concentration of the stack gas Method 3A or 3B at 40 CFR part 60, appendix A-2 of this chapter, or ANSI/ASME PTC 19.10-1981. a
d. Measure the moisture content of the stack gas Method 4 at 40 CFR part 60, appendix A-3 of this chapter.
e. Measure the hydrogen chloride emission concentration Method 26 or 26A (M26 or M26A) at 40 CFR part 60, appendix A-8 of this chapter.
f. Convert emissions concentration to lb per MMBtu emission rates Method 19 F-factor methodology at 40 CFR part 60, appendix A-7 of this chapter.
4. Mercury a. Select sampling ports location and the number of traverse points Method 1 at 40 CFR part 60, appendix A-1 of this chapter.
b. Determine velocity and volumetric flow-rate of the stack gas Method 2, 2F, or 2G at 40 CFR part 60, appendix A-1 or A-2 of this chapter.
c. Determine oxygen or carbon dioxide concentration of the stack gas Method 3A or 3B at 40 CFR part 60, appendix A-1 of this chapter, or ANSI/ASME PTC 19.10-1981. a
d. Measure the moisture content of the stack gas Method 4 at 40 CFR part 60, appendix A-3 of this chapter.
e. Measure the mercury emission concentration Method 29, 30A, or 30B (M29, M30A, or M30B) at 40 CFR part 60, appendix A-8 of this chapter or Method 101A at 40 CFR part 61, appendix B of this chapter, or ASTM Method D6784. a
f. Convert emissions concentration to lb per MMBtu emission rates Method 19 F-factor methodology at 40 CFR part 60, appendix A-7 of this chapter.
5. CO a. Select the sampling ports location and the number of traverse points Method 1 at 40 CFR part 60, appendix A-1 of this chapter.
b. Determine oxygen concentration of the stack gas Method 3A or 3B at 40 CFR part 60, appendix A-3 of this chapter, or ASTM D6522-00 (Reapproved 2005), or ANSI/ASME PTC 19.10-1981. a
c. Measure the moisture content of the stack gas Method 4 at 40 CFR part 60, appendix A-3 of this chapter.
d. Measure the CO emission concentration Method 10 at 40 CFR part 60, appendix A-4 of this chapter. Use a measurement span value of 2 times the concentration of the applicable emission limit.

[76 FR 15664, Mar. 21, 2011, as amended at 78 FR 7200, Jan. 31, 2013; 80 FR 72825, Nov. 20, 2015]

Table 6 to Subpart DDDDD of Part 63 - Fuel Analysis Requirements

As stated in §63.7521, you must comply with the following requirements for fuel analysis testing for existing, new or reconstructed affected sources. However, equivalent methods (as defined in §63.7575) may be used in lieu of the prescribed methods at the discretion of the source owner or operator:

Table 6 to Subpart DDDDD of Part 63 - Fuel Analysis Requirements
To conduct a fuel analysis for the following pollutant . . . You must . . . Using . . .
a Incorporated by reference, see §63.14.
1. Mercury a. Collect fuel samples Procedure in §63.7521(c) or ASTM D5192 a, or ASTM D7430 a, or ASTM D6883 a, or ASTM D2234/D2234M a (for coal) or EPA 1631 or EPA 1631E or ASTM D6323 a (for solid), or EPA 821-R-01-013 (for liquid or solid), or ASTM D4177 a (for liquid), or ASTM D4057 a (for liquid), or equivalent.
b. Composite fuel samples Procedure in §63.7521(d) or equivalent.
c. Prepare composited fuel samples EPA SW-846-3050B a (for solid samples), ASTM D2013/D2013M a (for coal), ASTM D5198 a (for biomass), or EPA 3050 a (for solid fuel), or EPA 821-R-01-013 a (for liquid or solid), or equivalent.
d. Determine heat content of the fuel type ASTM D5865 a (for coal) or ASTM E711 a (for biomass), or ASTM D5864 a for liquids and other solids, or ASTM D240 a or equivalent.
e. Determine moisture content of the fuel type ASTM D3173 a, ASTM E871 a, or ASTM D5864 a, or ASTM D240 a, or ASTM D95 a (for liquid fuels), or ASTM D4006 a (for liquid fuels), or equivalent.
f. Measure mercury concentration in fuel sample ASTM D6722 a (for coal), EPA SW-846-7471B a or EPA 1631 or EPA 1631E a (for solid samples), or EPA SW-846-7470A a or EPA SW-846-7471B a (for liquid samples), or EPA 821-R-01-013 a (for liquid or solid), or equivalent.
g. Convert concentration into units of pounds of mercury per MMBtu of heat content For fuel mixtures use Equation 8 in §63.7530.
2. HCl a. Collect fuel samples Procedure in §63.7521(c) or ASTM D5192 a, or ASTM D7430 a, or ASTM D6883 a, or ASTM D2234/D2234M a (for coal) or ASTM D6323 a (for coal or biomass), ASTM D4177 a (for liquid fuels) or ASTM D4057 a (for liquid fuels), or equivalent.
b. Composite fuel samples Procedure in §63.7521(d) or equivalent.
c. Prepare composited fuel samples EPA SW-846-3050B a (for solid samples), ASTM D2013/D2013M a (for coal), or ASTM D5198 a (for biomass), or EPA 3050 a or equivalent.
d. Determine heat content of the fuel type ASTM D5865 a (for coal) or ASTM E711 a (for biomass), ASTM D5864 a, ASTM D240 a or equivalent.
e. Determine moisture content of the fuel type ASTM D3173 a or ASTM E871 a, or D5864 a, or ASTM D240 a, or ASTM D95 a (for liquid fuels), or ASTM D4006 a (for liquid fuels), or equivalent.
f. Measure chlorine concentration in fuel sample EPA SW-846-9250 a, ASTM D6721 a, ASTM D4208 a (for coal), or EPA SW-846-5050 a or ASTM E776 a (for solid fuel), or EPA SW-846-9056 a or SW-846-9076 a (for solids or liquids) or equivalent.
g. Convert concentrations into units of pounds of HCl per MMBtu of heat content For fuel mixtures use Equation 7 in §63.7530 and convert from chlorine to HCl by multiplying by 1.028.
3. Mercury Fuel Specification for other gas 1 fuels a. Measure mercury concentration in the fuel sample and convert to units of micrograms per cubic meter, or Method 30B (M30B) at 40 CFR part 60, appendix A-8 of this chapter or ASTM D5954 a, ASTM D6350 a, ISO 6978-1:2003(E) a, or ISO 6978-2:2003(E) a, or EPA-1631 a or equivalent.
b. Measure mercury concentration in the exhaust gas when firing only the other gas 1 fuel is fired in the boiler or process heater Method 29, 30A, or 30B (M29, M30A, or M30B) at 40 CFR part 60, appendix A-8 of this chapter or Method 101A or Method 102 at 40 CFR part 61, appendix B of this chapter, or ASTM Method D6784 a or equivalent.
4. TSM a. Collect fuel samples Procedure in §63.7521(c) or ASTM D5192 a, or ASTM D7430 a, or ASTM D6883 a, or ASTM D2234/D2234M a (for coal) or ASTM D6323 a (for coal or biomass), or ASTM D4177 a, (for liquid fuels), or ASTM D4057 a (for liquid fuels), or equivalent.
b. Composite fuel samples Procedure in §63.7521(d) or equivalent.
c. Prepare composited fuel samples EPA SW-846-3050B a (for solid samples), ASTM D2013/D2013M a (for coal), ASTM D5198 a or TAPPI T266 a (for biomass), or EPA 3050 a or equivalent.
d. Determine heat content of the fuel type ASTM D5865 a (for coal) or ASTM E711 a (for biomass), or ASTM D5864 a for liquids and other solids, or ASTM D240 a or equivalent.
e. Determine moisture content of the fuel type ASTM D3173 a or ASTM E871 a, or D5864 a, or ASTM D240 a, or ASTM D95 a (for liquid fuels), or ASTM D4006 a (for liquid fuels), or ASTM D4177 a (for liquid fuels) or ASTM D4057 a (for liquid fuels), or equivalent.
f. Measure TSM concentration in fuel sample ASTM D3683 a, or ASTM D4606 a, or ASTM D6357 a or EPA 200.8 a or EPA SW-846-6020 a, or EPA SW-846-6020A a, or EPA SW-846-6010C a, EPA 7060 a or EPA 7060A a (for arsenic only), or EPA SW-846-7740 a (for selenium only).
g. Convert concentrations into units of pounds of TSM per MMBtu of heat content For fuel mixtures use Equation 9 in §63.7530.

[83 FR 56725, Nov. 14, 2018]

Table 7 to Subpart DDDDD of Part 63—Establishing Operating Limits ab

Table 7 to Subpart DDDDD of Part 63—Establishing Operating Limits ab[As stated in §63.7520, you must comply with the following requirements for establishing operating limits:]
If you have an applicable emission limit for . . . And your operating limits are based on . . . You must . . . Using . . . According to the following requirements
a Operating limits must be confirmed or reestablished during performance tests.
b If you conduct multiple performance tests, you must set the minimum liquid flow rate and pressure drop operating limits at the higher of the minimum values established during the performance tests. For a minimum oxygen level, if you conduct multiple performance tests, you must set the minimum oxygen level at the lower of the minimum values established during the performance tests. For maximum operating load, if you conduct multiple performance tests, you must set the maximum operating load at the lower of the maximum values established during the performance tests.
1. PM, TSM, or mercury a. Wet scrubber operating parameters i. Establish a site-specific minimum scrubber pressure drop and minimum flow rate operating limit according to §63.7530(b) (1) Data from the scrubber pressure drop and liquid flow rate monitors and the PM, TSM, or mercury performance test (a) You must collect scrubber pressure drop and liquid flow rate data every 15 minutes during the entire period of the performance tests.
(b) Determine the lowest hourly average scrubber pressure drop and liquid flow rate by computing the hourly averages using all of the 15-minute readings taken during each performance test.
b. Electrostatic precipitator operating parameters (option only for units that operate wet scrubbers) i. Establish a site-specific minimum total secondary electric power input according to §63.7530(b) (1) Data from the voltage and secondary amperage monitors during the PM or mercury performance test (a) You must collect secondary voltage and secondary amperage for each ESP cell and calculate total secondary electric power input data every 15 minutes during the entire period of the performance tests.
(b) Determine the average total secondary electric power input by computing the hourly averages using all of the 15-minute readings taken during each performance test.
c. Opacity i. Establish a site-specific maximum opacity level (1) Data from the opacity monitoring system during the PM performance test (a) You must collect opacity readings every 15 minutes during the entire period of the performance tests.
(b) Determine the average hourly opacity reading by computing the hourly averages using all of the 15-minute readings taken during each performance test.
(c) Determine the highest hourly average opacity reading measured during the test run demonstrating compliance with the PM (or TSM) emission limitation.
2. HCl a. Wet scrubber operating parameters i. Establish site-specific minimum effluent pH and flow rate operating limits according to §63.7530(b) (1) Data from the pH and liquid flow-rate monitors and the HCl performance test (a) You must collect pH and liquid flow-rate data every 15 minutes during the entire period of the performance tests.
(b) Determine the hourly average pH and liquid flow rate by computing the hourly averages using all of the 15-minute readings taken during each performance test.
b. Dry scrubber operating parameters i. Establish a site-specific minimum sorbent injection rate operating limit according to §63.7530(b). If different acid gas sorbents are used during the HCl performance test, the average value for each sorbent becomes the site-specific operating limit for that sorbent (1) Data from the sorbent injection rate monitors and HCl or mercury performance test (a) You must collect sorbent injection rate data every 15 minutes during the entire period of the performance tests.
(b) Determine the hourly average sorbent injection rate by computing the hourly averages using all of the 15-minute readings taken during each performance test.
(c) Determine the lowest hourly average of the three test run averages established during the performance test as your operating limit. When your unit operates at lower loads, multiply your sorbent injection rate by the load fraction, as defined in §63.7575, to determine the required injection rate.
c. Alternative Maximum SO 2 emission rate i. Establish a site-specific maximum SO 2 emission rate operating limit according to §63.7530(b) (1) Data from SO 2 CEMS and the HCl performance test (a) You must collect the SO 2 emissions data according to §63.7525(m) during the most recent HCl performance tests.
(b) The maximum SO 2 emission rate is equal to the highest hourly average SO 2 emission rate measured during the most recent HCl performance tests.
3. Mercury a. Activated carbon injection i. Establish a site-specific minimum activated carbon injection rate operating limit according to §63.7530(b) (1) Data from the activated carbon rate monitors and mercury performance test (a) You must collect activated carbon injection rate data every 15 minutes during the entire period of the performance tests.
(b) Determine the hourly average activated carbon injection rate by computing the hourly averages using all of the 15-minute readings taken during each performance test.
(c) Determine the lowest hourly average established during the performance test as your operating limit. When your unit operates at lower loads, multiply your activated carbon injection rate by the load fraction, as defined in §63.7575, to determine the required injection rate.
4. Carbon monoxide for which compliance is demonstrated by a performance test a. Oxygen i. Establish a unit-specific limit for minimum oxygen level according to §63.7530(b) (1) Data from the oxygen analyzer system specified in §63.7525(a) (a) You must collect oxygen data every 15 minutes during the entire period of the performance tests.
(b) Determine the hourly average oxygen concentration by computing the hourly averages using all of the 15-minute readings taken during each performance test.
(c) Determine the lowest hourly average established during the performance test as your minimum operating limit.
5. Any pollutant for which compliance is demonstrated by a performance test a. Boiler or process heater operating load i. Establish a unit specific limit for maximum operating load according to §63.7520(c) (1) Data from the operating load monitors or from steam generation monitors (a) You must collect operating load or steam generation data every 15 minutes during the entire period of the performance test.
(b) Determine the average operating load by computing the hourly averages using all of the 15-minute readings taken during each performance test.
(c) Determine the highest hourly average of the three test run averages during the performance test, and multiply this by 1.1 (110 percent) as your operating limit.

[80 FR 72827, Nov. 20, 2015; 87 FR 60853, Oct. 6, 2022]

Table 8 to Subpart DDDDD of Part 63 - Demonstrating Continuous Compliance

As stated in §63.7540, you must show continuous compliance with the emission limitations for each boiler or process heater according to the following:

Table 8 to Subpart DDDDD of Part 63 - Demonstrating Continuous Compliance
If you must meet the following operating limits or work practice standards . . . You must demonstrate continuous compliance by . . .
1. Opacity a. Collecting the opacity monitoring system data according to §63.7525(c) and §63.7535; and
b. Reducing the opacity monitoring data to 6-minute averages; and
c. Maintaining daily block average opacity to less than or equal to 10 percent or the highest hourly average opacity reading measured during the performance test run demonstrating compliance with the PM (or TSM) emission limitation.
2. PM CPMS a. Collecting the PM CPMS output data according to §63.7525;
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average PM CPMS output data to less than the operating limit established during the performance test according to §63.7530(b)(4).
3. Fabric Filter Bag Leak Detection Operation Installing and operating a bag leak detection system according to §63.7525 and operating the fabric filter such that the requirements in §63.7540(a)(7) are met.
4. Wet Scrubber Pressure Drop and Liquid Flow-rate a. Collecting the pressure drop and liquid flow rate monitoring system data according to §§63.7525 and 63.7535; and
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average pressure drop and liquid flow-rate at or above the operating limits established during the performance test according to §63.7530(b).
5. Wet Scrubber pH a. Collecting the pH monitoring system data according to §§63.7525 and 63.7535; and
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average pH at or above the operating limit established during the performance test according to §63.7530(b).
6. Dry Scrubber Sorbent or Carbon Injection Rate a. Collecting the sorbent or carbon injection rate monitoring system data for the dry scrubber according to §§63.7525 and 63.7535; and
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average sorbent or carbon injection rate at or above the minimum sorbent or carbon injection rate as defined in §63.7575.
7. Electrostatic Precipitator Total Secondary Electric Power Input a. Collecting the total secondary electric power input monitoring system data for the electrostatic precipitator according to §§63.7525 and 63.7535; and
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average total secondary electric power input at or above the operating limits established during the performance test according to §63.7530(b).
8. Emission limits using fuel analysis a. Conduct monthly fuel analysis for HCl or mercury or TSM according to Table 6 to this subpart; and
b. Reduce the data to 12-month rolling averages; and
c. Maintain the 12-month rolling average at or below the applicable emission limit for HCl or mercury or TSM in Tables 1 and 2 or 11 through 15 to this subpart.
d. Calculate the HCI, mercury, and/or TSM emission rate from the boiler or process heater in units of lb/MMBtu using Equation 15 and Equations 16, 17, and/or 18 in §63.7530.
9. Oxygen content a. Continuously monitor the oxygen content using an oxygen analyzer system according to §63.7525(a). This requirement does not apply to units that install an oxygen trim system since these units will set the trim system to the level specified in §63.7525(a)(7).
b. Reducing the data to 30-day rolling averages; and
c. Maintain the 30-day rolling average oxygen content at or above the lowest hourly average oxygen level measured during the CO performance test.
10. Boiler or process heater operating load a. Collecting operating load data or steam generation data every 15 minutes.
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average operating load such that it does not exceed 110 percent of the highest hourly average operating load recorded during the performance test according to §63.7520(c).
11. SO2 emissions using SO2 CEMS a. Collecting the SO2 CEMS output data according to §63.7525;
b. Reducing the data to 30-day rolling averages; and
c. Maintaining the 30-day rolling average SO2 CEMS emission rate to a level at or below the highest hourly SO2 rate measured during the HCl performance test according to §63.7530.

[78 FR 7204, Jan. 31, 2013, as amended at 80 FR 72829, Nov. 20, 2015; 87 FR 60855, Oct. 6, 2022]

Table 9 to Subpart DDDDD of Part 63 - Reporting Requirements

As stated in §63.7550, you must comply with the following requirements for reports:

Table 9 to Subpart DDDDD of Part 63 - Reporting Requirements
You must submit a(n) The report must contain . . . You must submit the report . . .
1. Compliance report a. Information required in §63.7550(c)(1) through (5); and Semiannually, annually, biennially, or every 5 years according to the requirements in §63.7550(b).
b. If there are no deviations from any emission limitation (emission limit and operating limit) that applies to you and there are no deviations from the requirements for work practice standards for periods of startup and shutdown in Table 3 to this subpart that apply to you, a statement that there were no deviations from the emission limitations and work practice standards during the reporting period. If there were no periods during which the CMSs, including continuous emissions monitoring system, continuous opacity monitoring system, and operating parameter monitoring systems, were out-of-control as specified in §63.8(c)(7), a statement that there were no periods during which the CMSs were out-of-control during the reporting period; and
c. If you have a deviation from any emission limitation (emission limit and operating limit) where you are not using a CMS to comply with that emission limit or operating limit, or a deviation from a work practice standard for periods of startup and shutdown, during the reporting period, the report must contain the information in §63.7550(d); and
d. If there were periods during which the CMSs, including continuous emissions monitoring system, continuous opacity monitoring system, and operating parameter monitoring systems, were out-of-control as specified in §63.8(c)(7), or otherwise not operating, the report must contain the information in §63.7550(e)

[76 FR 15664, Mar. 21, 2011, as amended at 78 FR 7205, Jan. 31, 2013; 80 FR 72830, Nov. 20, 2015]

Table 10 to Subpart DDDDD of Part 63 - Applicability of General Provisions to Subpart DDDDD

As stated in §63.7565, you must comply with the applicable General Provisions according to the following:

Table 10 to Subpart DDDDD of Part 63 - Applicability of General Provisions to Subpart DDDDD
Citation Subject Applies to subpart DDDDD
§63.1 Applicability Yes.
§63.2 Definitions Yes. Additional terms defined in §63.7575
§63.3 Units and Abbreviations Yes.
§63.4 Prohibited Activities and Circumvention Yes.
§63.5 Preconstruction Review and Notification Requirements Yes.
§63.6(a), (b)(1)-(b)(5), (b)(7), (c) Compliance with Standards and Maintenance Requirements Yes.
§63.6(e)(1)(i) General duty to minimize emissions. No. See §63.7500(a)(3) for the general duty requirement.
§63.6(e)(1)(ii) Requirement to correct malfunctions as soon as practicable. No.
§63.6(e)(3) Startup, shutdown, and malfunction plan requirements. No.
§63.6(f)(1) Startup, shutdown, and malfunction exemptions for compliance with non-opacity emission standards. No.
§63.6(f)(2) and (3) Compliance with non-opacity emission standards. Yes.
§63.6(g) Use of alternative standards Yes, except §63.7555(d)(13) specifies the procedure for application and approval of an alternative timeframe with the PM controls requirement in the startup work practice (2).
§63.6(h)(1) Startup, shutdown, and malfunction exemptions to opacity standards. No. See §63.7500(a).
§63.6(h)(2) to (h)(9) Determining compliance with opacity emission standards No. Subpart DDDDD specifies opacity as an operating limit not an emission standard.
§63.6(i) Extension of compliance Yes. Note: Facilities may also request extensions of compliance for the installation of combined heat and power, waste heat recovery, or gas pipeline or fuel feeding infrastructure as a means of complying with this subpart.
§63.6(j) Presidential exemption. Yes.
§63.7(a), (b), (c), and (d) Performance Testing Requirements Yes.
§63.7(e)(1) Conditions for conducting performance tests No. Subpart DDDDD specifies conditions for conducting performance tests at §63.7520(a) to (c).
§63.7(e)(2)-(e)(9), (f), (g), and (h) Performance Testing Requirements Yes.
§63.8(a) and (b) Applicability and Conduct of Monitoring Yes.
§63.8(c)(1) Operation and maintenance of CMS Yes.
§63.8(c)(1)(i) General duty to minimize emissions and CMS operation No. See §63.7500(a)(3).
§63.8(c)(1)(ii) Operation and maintenance of CMS Yes.
§63.8(c)(1)(iii) Startup, shutdown, and malfunction plans for CMS No.
§63.8(c)(2) to (c)(9) Operation and maintenance of CMS Yes.
§63.8(d)(1) and (2) Monitoring Requirements, Quality Control Program Yes.
§63.8(d)(3) Written procedures for CMS Yes, except for the last sentence, which refers to a startup, shutdown, and malfunction plan. Startup, shutdown, and malfunction plans are not required.
§63.8(e) Performance evaluation of a CMS Yes.
§63.8(f) Use of an alternative monitoring method. Yes.
§63.8(g) Reduction of monitoring data Yes.
§63.9 Notification Requirements Yes.
§63.10(a), (b)(1) Recordkeeping and Reporting Requirements Yes.
§63.10(b)(2)(i) Recordkeeping of occurrence and duration of startups or shutdowns Yes.
§63.10(b)(2)(ii) Recordkeeping of malfunctions No. See §63.7555(d)(7) for recordkeeping of occurrence and duration and §63.7555(d)(8) for actions taken during malfunctions.
§63.10(b)(2)(iii) Maintenance records Yes.
§63.10(b)(2)(iv) and (v) Actions taken to minimize emissions during startup, shutdown, or malfunction No.
§63.10(b)(2)(vi) Recordkeeping for CMS malfunctions Yes.
§63.10(b)(2)(vii) to (xiv) Other CMS requirements Yes.
§63.10(b)(3) Recordkeeping requirements for applicability determinations No.
§63.10(c)(1) to (9) Recordkeeping for sources with CMS Yes.
§63.10(c)(10) and (11) Recording nature and cause of malfunctions, and corrective actions No. See §63.7555(d)(7) for recordkeeping of occurrence and duration and §63.7555(d)(8) for actions taken during malfunctions.
§63.10(c)(12) and (13) Recordkeeping for sources with CMS Yes.
§63.10(c)(15) Use of startup, shutdown, and malfunction plan No.
§63.10(d)(1) and (2) General reporting requirements Yes.
§63.10(d)(3) Reporting opacity or visible emission observation results No.
§63.10(d)(4) Progress reports under an extension of compliance Yes.
§63.10(d)(5) Startup, shutdown, and malfunction reports No. See §63.7550(c)(11) for malfunction reporting requirements.
§63.10(e) Additional reporting requirements for sources with CMS Yes.
§63.10(f) Waiver of recordkeeping or reporting requirements Yes.
§63.11 Control Device Requirements No.
§63.12 State Authority and Delegation Yes.
§63.13-63.16 Addresses, Incorporation by Reference, Availability of Information, Performance Track Provisions Yes.
§63.1(a)(5),(a)(7)-(a)(9), (b)(2), (c)(3)-(4), (d), 63.6(b)(6), (c)(3), (c)(4), (d), (e)(2), (e)(3)(ii), (h)(3), (h)(5)(iv), 63.8(a)(3), 63.9(b)(3), (h)(4), 63.10(c)(2)-(4), (c)(9). Reserved No.

[76 FR 15664, Mar. 21, 2011, as amended at 78 FR 7205, Jan. 31, 2013; 80 FR 72830, Nov. 20, 2015]

Table 11 to Subpart DDDDD of Part 63 - Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After June 4, 2010, and Before May 20, 2011

Table 11 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After June 4, 2010, and Before May 20, 2011
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during periods of startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit, you can skip testing according to §63.7515 if all of the other provision of §63.7515 are met. For all other pollutants that do not contain a footnote “a”, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c An owner or operator may determine compliance with the carbon monoxide emissions limit using carbon dioxide as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit, and must also take into account that the 3% oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
1. Units in all subcategories designed to burn solid fuel a. HCl 0.022 lb per MMBtu of heat input For M26A, collect a minimum of 1 dscm per run; for M26 collect a minimum of 120 liters per run.
2. Units in all subcategories designed to burn solid fuel that combust at least 10 percent biomass/bio-based solids on an annual heat input basis and less than 10 percent coal/solid fossil fuels on an annual heat input basis a. Mercury 8.0E-07 a lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
3. Units in all subcategories designed to burn solid fuel that combust at least 10 percent coal/solid fossil fuels on an annual heat input basis and less than 10 percent biomass/bio-based solids on an annual heat input basis a. Mercury 2.0E-06 lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
4. Units design to burn coal/solid fossil fuel a. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
5. Pulverized coal boilers designed to burn coal/solid fossil fuel a. Carbon monoxide (CO) (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
6. Stokers designed to burn coal/solid fossil fuel a. CO (or CEMS). 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3 percent oxygen , c 10-day rolling average) 1 hr minimum sampling time.
7. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
8. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
9. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 620 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (390 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (2.6E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
10. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 560 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (4.0E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run
11. Fluidized bed units designed to burn biomass/bio-based solids a. CO (or CEMS) 230 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 9.8E-03 lb per MMBtu of heat input; or (8.3E-05 a lb per MMBtu of heat input) Collect a minimum of 3 dscm per run
12. Suspension burners designed to burn biomass/bio-based solids a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3 percent oxygen c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (6.5E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
13. Dutch Ovens/Pile burners designed to burn biomass/bio-based solids a. CO (or CEMS) 1,010 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3 percent oxygen c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 8.0E-03 lb per MMBtu of heat input; or (3.9E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
14. Fuel cell units designed to burn biomass/bio-based solids a. CO 910 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
15. Hybrid suspension grate boiler designed to burn biomass/bio-based solids a. CO (or CEMS) 1,100 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.6E-02 lb per MMBtu of heat input; or (4.4E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run
16. Units designed to burn liquid fuel a. HCl 4.4E-04 lb per MMBtu of heat input For M26A: Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run
b. Mercury. 4.8E-07 a lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
17. Units designed to burn heavy liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.3E-02 lb per MMBtu of heat input; or (7.5E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
18. Units designed to burn light liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-03 a lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run
19. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average based on stack test 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.3E-02 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) Collect a minimum of 4 dscm per run
20. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input For M26A, Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
d. Filterable PM (or TSM) 6.7E-03 lb per MMBtu of heat input; or (2.1E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.

[80 FR 72831, Nov. 20, 2015; 87 FR 60855, Oct. 6, 2022]

Table 12 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After May 20, 2011, and Before December 23, 2011

Table 12 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After May 20, 2011, and Before December 23, 2011
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during periods of startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit, you can skip testing according to §63.7515 if all of the other provision of §63.7515 are met. For all other pollutants that do not contain a footnote “a”, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c An owner or operator may determine compliance with the carbon monoxide emissions limit using carbon dioxide as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit, and must also take into account that the 3% oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
1. Units in all subcategories designed to burn solid fuel a. HCl 0.022 lb per MMBtu of heat input For M26A, collect a minimum of 1 dscm per run; for M26 collect a minimum of 120 liters per run.
b. Mercury 3.5E-06 a lb per MMBtu of heat input For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
2. Units design to burn coal/solid fossil fuel a. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
3. Pulverized coal boilers designed to burn coal/solid fossil fuel a. Carbon monoxide (CO) (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
4. Stokers designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
5. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
6. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
7. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 620 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (390 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (2.6E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
8. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 460 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (4.0E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
9. Fluidized bed units designed to burn biomass/bio-based solids a. CO (or CEMS) 260 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 9.8E-03 lb per MMBtu of heat input; or (8.3E-05 a lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
10. Suspension burners designed to burn biomass/bio-based solids a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (6.5E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
11. Dutch Ovens/Pile burners designed to burn biomass/bio-based solids a. CO (or CEMS) 470 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.2E-03 lb per MMBtu of heat input; or (3.9E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
12. Fuel cell units designed to burn biomass/bio-based solids a. CO 910 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
13. Hybrid suspension grate boiler designed to burn biomass/bio-based solids a. CO (or CEMS) 1,500 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.6E-02 lb per MMBtu of heat input; or (4.4E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
14. Units designed to burn liquid fuel a. HCl 4.4E-04 lb per MMBtu of heat input For M26A: Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
b. Mercury 4.8E-07 a lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
15. Units designed to burn heavy liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.3E-02 lb per MMBtu of heat input; or (7.5E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
16. Units designed to burn light liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.3E-03 a lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
17. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average based on stack test 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.3E-02 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) Collect a minimum of 4 dscm per run.
18. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input For M26A, Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
d. Filterable PM (or TSM) 6.7E-03 lb per MMBtu of heat input; or (2.1E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.

[80 FR 72834, Nov. 20, 2015; 87 FR 60857, Oct. 6, 2022]

Table 13 to Subpart DDDDD of Part 63 - Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After December 23, 2011, and Before April 1, 2013

Table 13 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters That Commenced Construction or Reconstruction After December 23, 2011, and Before April 1, 2013
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during periods of startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit and you are not required to conduct testing for CEMS or CPMS monitor certification, you can skip testing according to §63.7515 if all of the other provision of §63.7515 are met. For all other pollutants that do not contain a footnote “a”, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c An owner or operator may determine compliance with the carbon monoxide emissions limit using carbon dioxide as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit, and must also take into account that the 3% oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
1. Units in all subcategories designed to burn solid fuel a. HCl 0.022 lb per MMBtu of heat input For M26A, collect a minimum of 1 dscm per run; for M26 collect a minimum of 120 liters per run.
b. Mercury 8.6E-07 a lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
2. Pulverized coal boilers designed to burn coal/solid fossil fuel a. Carbon monoxide (CO) (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.8E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
3. Stokers designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.8E-02 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
4. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
5. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
6. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 620 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (410 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (2.6E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
7. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 460 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.2E-01 lb per MMBtu of heat input; or (4.0E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
8. Fluidized bed units designed to burn biomass/bio-based solids a. CO (or CEMS) 230 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 9.8E-03 lb per MMBtu of heat input; or (8.3E-05 a lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
9. Suspension burners designed to burn biomass/bio-based solids a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 5.1E-02 lb per MMBtu of heat input; or (6.5E-03 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
10. Dutch Ovens/Pile burners designed to burn biomass/bio-based solids a. CO (or CEMS) 810 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.6E-02 lb per MMBtu of heat input; or (3.9E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
11. Fuel cell units designed to burn biomass/bio-based solids a. CO 910 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
12. Hybrid suspension grate boiler designed to burn biomass/bio-based solids a. CO (or CEMS) 1,500 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3 percent oxygen, c 30-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.6E-02 lb per MMBtu of heat input; or (4.4E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
13. Units designed to burn liquid fuel a. HCl 1.2E-03 lb per MMBtu of heat input For M26A: Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
b. Mercury 4.9E-07 a lb per MMBtu of heat input For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
14. Units designed to burn heavy liquid fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (18 ppm by volume on a dry basis corrected to 3 percent oxygen, c 10-day rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.3E-03 lb per MMBtu of heat input; or (7.5E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
15. Units designed to burn light liquid fuel a. CO (or CEMS) 130 a ppm by volume on a dry basis corrected to 3 percent oxygen; or (60 ppm by volume on a dry basis corrected to 3 percent oxygen, c 1-day block average). 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-03 a lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.
16. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average based on stack test; or (91 ppm by volume on a dry basis corrected to 3 percent oxygen, c 3-hour rolling average) 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.3E-02 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) Collect a minimum of 2 dscm per run.
17. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3 percent oxygen 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input For M26A, Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
d. Filterable PM (or TSM) 6.7E-03 lb per MMBtu of heat input; or (2.1E-04 lb per MMBtu of heat input) Collect a minimum of 3 dscm per run.

[78 FR 7210, Jan. 31, 2013, as amended at 80 FR 72836, Nov. 20, 2015; 87 FR 60860, Oct. 6, 2022]

Table 14 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters c

[As stated in §63.7500, you may continue to comply with the following applicable emission limits until October 6, 2025: [Units with heat input capacity of 10 million Btu per hour or greater]]

Table 14 to Subpart DDDDD of Part 63—Alternative Emission Limits for New or Reconstructed Boilers and Process Heaters c
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during startup and shutdown . . . Or the emissions must not exceed the following alternative output-based limits, except during startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit, you can skip testing according to §63.7515 if all of the other provisions of §63.7515 are met. For all other pollutants that do not contain a footnote “a”, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c If your affected source is a new or reconstructed affected source that commenced construction or reconstruction after June 4, 2010, and before April 1, 2013, you may comply with the emission limits in Table 11, 12, or 13 to this subpart until January 31, 2016. On and after January 31, 2016, but before October 6, 2025 you may comply with the emission limits in this Table 14. On and after October 6, 2025, you must comply with the emission limits in Table 1 to this subpart.
d An owner or operator may determine compliance with the carbon monoxide emissions limit using carbon dioxide as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit, and must also take into account that the 3% oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
1. Units in all subcategories designed to burn solid fuel. a. HCl 2.2E-02 lb per MMBtu of heat input 2.5E-02 lb per MMBtu of steam output or 0.28 lb per MWh For M26A, collect a minimum of 1 dscm per run; for M26 collect a minimum of 120 liters per run.
b. Mercury 8.0E-07 a lb per MMBtu of heat input 8.7E-07 a lb per MMBtu of steam output or 1.1E-05 a lb per MWh For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
2. Units designed to burn coal/solid fossil fuel a. Filterable PM (or TSM) 1.1E-03 lb per MMBtu of heat input; or (2.3E-05 lb per MMBtu of heat input) 1.1E-03 lb per MMBtu of steam output or 1.4E-02 lb per MWh; or (2.7E-05 lb per MMBtu of steam output or 2.9E-04 lb per MWh) Collect a minimum of 3 dscm per run.
3. Pulverized coal boilers designed to burn coal/solid fossil fuel a. Carbon monoxide (CO) (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 0.11 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
4. Stokers/others designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 0.12 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
5. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 0.11 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
6. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3- percent oxygen, d 30-day rolling average) 1.2E-01 lb per MMBtu of steam output or 1.5 lb per MWh; 3-run average 1 hr minimum sampling time.
7. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 620 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (390 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 5.8E-01 lb per MMBtu of steam output or 6.8 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (2.6E-05 lb per MMBtu of heat input) 3.5E-02 lb per MMBtu of steam output or 4.2E-01 lb per MWh; or (2.7E-05 lb per MMBtu of steam output or 3.7E-04 lb per MWh) Collect a minimum of 2 dscm per run.
8. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 460 ppm by volume on a dry basis corrected to 3-percent oxygen 4.2E-01 lb per MMBtu of steam output or 5.1 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (4.0E-03 lb per MMBtu of heat input) 3.5E-02 lb per MMBtu of steam output or 4.2E-01 lb per MWh; or (4.2E-03 lb per MMBtu of steam output or 5.6E-02 lb per MWh) Collect a minimum of 2 dscm per run.
9. Fluidized bed units designed to burn biomass/bio-based solids a. CO (or CEMS) 230 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 2.2E-01 lb per MMBtu of steam output or 2.6 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 9.8E-03 lb per MMBtu of heat input; or (8.3E-05 a lb per MMBtu of heat input) 1.2E-02 lb per MMBtu of steam output or 0.14 lb per MWh; or (1.1E-04 a lb per MMBtu of steam output or 1.2E-03 a lb per MWh) Collect a minimum of 3 dscm per run.
10. Suspension burners designed to burn biomass/bio-based solids a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3-percent oxygen, d 10-day rolling average) 1.9 lb per MMBtu of steam output or 27 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.0E-02 lb per MMBtu of heat input; or (6.5E-03 lb per MMBtu of heat input) 3.1E-02 lb per MMBtu of steam output or 4.2E-01 lb per MWh; or (6.6E-03 lb per MMBtu of steam output or 9.1E-02 lb per MWh) Collect a minimum of 2 dscm per run.
11. Dutch Ovens/Pile burners designed to burn biomass/bio-based solids a. CO (or CEMS) 330 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3-percent oxygen, d 10-day rolling average) 3.5E-01 lb per MMBtu of steam output or 3.6 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.2E-03 lb per MMBtu of heat input; or (3.9E-05 lb per MMBtu of heat input) 4.3E-03 lb per MMBtu of steam output or 4.5E-02 lb per MWh; or (5.2E-05 lb per MMBtu of steam output or 5.5E-04 lb per MWh) Collect a minimum of 3 dscm per run.
12. Fuel cell units designed to burn biomass/bio-based solids a. CO 910 ppm by volume on a dry basis corrected to 3-percent oxygen 1.1 lb per MMBtu of steam output or 1.0E 01 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) 3.0E-02 lb per MMBtu of steam output or 2.8E-01 lb per MWh; or (5.1E-05 lb per MMBtu of steam output or 4.1E-04 lb per MWh) Collect a minimum of 2 dscm per run.
13. Hybrid suspension grate boiler designed to burn biomass/bio-based solids a. CO (or CEMS) 1,100 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3-percent oxygen, d 30-day rolling average) 1.4 lb per MMBtu of steam output or 12 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.6E-02 lb per MMBtu of heat input; or (4.4E-04 lb per MMBtu of heat input) 3.3E-02 lb per MMBtu of steam output or 3.7E-01 lb per MWh; or (5.5E-04 lb per MMBtu of steam output or 6.2E-03 lb per MWh) Collect a minimum of 3 dscm per run.
14. Units designed to burn liquid fuel a. HCl 4.4E-04 lb per MMBtu of heat input 4.8E-04 lb per MMBtu of steam output or 6.1E-03 lb per MWh For M26A: Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
b. Mercury 4.8E-07 a lb per MMBtu of heat input 5.3E-07 a lb per MMBtu of steam output or 6.7E-06 a lb per MWh For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 4 dscm.
15. Units designed to burn heavy liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.3E-02 lb per MMBtu of heat input; or (7.5E-05 a lb per MMBtu of heat input) 1.5E-02 lb per MMBtu of steam output or 1.8E-01 lb per MWh; or (8.2E-05 a lb per MMBtu of steam output or 1.1E-03 a lb per MWh) Collect a minimum of 3 dscm per run.
16. Units designed to burn light liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.13 lb per MMBtu of steam output or 1.4 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-03 a lb per MMBtu of heat input; or (2.9E-05 lb per MMBtu of heat input) 1.2E-03 a lb per MMBtu of steam output or 1.6E-02 a lb per MWh; or (3.2E-05 lb per MMBtu of steam output or 4.0E-04 lb per MWh) Collect a minimum of 3 dscm per run.
17. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average based on stack test 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.3E-02 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) 2.5E-02 lb per MMBtu of steam output or 3.2E-01 lb per MWh; or (9.4E-04 lb per MMBtu of steam output or 1.2E-02 lb per MWh) Collect a minimum of 4 dscm per run.
18. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.16 lb per MMBtu of steam output or 1.0 lb per MWh 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input 2.9E-03 lb per MMBtu of steam output or 1.8E-02 lb per MWh For M26A, Collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input 1.4E-05 lb per MMBtu of steam output or 8.3E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
d. Filterable PM (or TSM) 6.7E-03 lb per MMBtu of heat input; or (2.1E-04 lb per MMBtu of heat input) 1.2E-02 lb per MMBtu of steam output or 7.0E-02 lb per MWh; or (3.5E-04 lb per MMBtu of steam output or 2.2E-03 lb per MWh) Collect a minimum of 3 dscm per run.

[87 FR 60860, Oct. 6, 2022]

Table 15 to Subpart DDDDD of Part 63—Alternative Emission Limits for Existing Boilers and Process Heaters d

[As stated in §63.7500, you may continue to comply with following emission limits until October 6, 2025: [Units with heat input capacity of 10 million Btu per hour or greater]]

Table 15 to Subpart DDDDD of Part 63—Alternative Emission Limits for Existing Boilers and Process Heaters d
If your boiler or process heater is in this subcategory . . . For the following pollutants . . . The emissions must not exceed the following emission limits, except during startup and shutdown . . . The emissions must not exceed the following alternative output-based limits, except during startup and shutdown . . . Using this specified sampling volume or test run duration . . .
a If you are conducting stack tests to demonstrate compliance and your performance tests for this pollutant for at least 2 consecutive years show that your emissions are at or below this limit, you can skip testing according to §63.7515 if all of the other provisions of §63.7515 are met. For all other pollutants that do not contain a footnote a, your performance tests for this pollutant for at least 2 consecutive years must show that your emissions are at or below 75 percent of this limit in order to qualify for skip testing.
b Incorporated by reference, see §63.14.
c An owner or operator may determine compliance with the carbon monoxide emissions limit using carbon dioxide as a diluent correction in place of oxygen as described in §63.7525(a)(1). EPA Method 19 F-factors in 40 CFR part 60, appendix A-7, and EPA Method 19 equations in 40 CFR part 60, appendix A-7, must be used to generate the appropriate CO 2 correction percentage for the fuel type burned in the unit, and must also take into account that the 3% oxygen correction is to be done on a dry basis. The methodology must account for any CO 2 being added to, or removed from, the emissions gas stream as a result of limestone injection, scrubber media, etc. This methodology must be detailed in the site-specific monitoring plan developed according to §63.7505(d).
d Before October 6, 2025 you may comply with the emission limits in this Table 15. On and after October 6, 2025, you must comply with the emission limits in Table 2 to this subpart.
1. Units in all subcategories designed to burn solid fuel a. HCl 2.2E-02 lb per MMBtu of heat input 2.5E-02 lb per MMBtu of steam output or 0.27 lb per MWh For M26A, Collect a minimum of 1 dscm per run; for M26, collect a minimum of 120 liters per run.
b. Mercury 5.7E-06 lb per MMBtu of heat input 6.4E-06 lb per MMBtu of steam output or 7.3E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 3 dscm.
2. Units design to burn coal/solid fossil fuel a. Filterable PM (or TSM) 4.0E-02 lb per MMBtu of heat input; or (5.3E-05 lb per MMBtu of heat input) 4.2E-02 lb per MMBtu of steam output or 4.9E-01 lb per MWh; or (5.6E-05 lb per MMBtu of steam output or 6.5E-04 lb per MWh) Collect a minimum of 2 dscm per run.
3. Pulverized coal boilers designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (320 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 0.11 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
4. Stokers/others designed to burn coal/solid fossil fuel a. CO (or CEMS) 160 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (340 ppm by volume on a dry basis corrected to 3- percent oxygen, c 30-day rolling average) 0.14 lb per MMBtu of steam output or 1.7 lb per MWh; 3-run average 1 hr minimum sampling time.
5. Fluidized bed units designed to burn coal/solid fossil fuel a. CO (or CEMS) 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (230 ppm by volume on a dry basis corrected to 3- percent oxygen, c 30-day rolling average) 0.12 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
6. Fluidized bed units with an integrated heat exchanger designed to burn coal/solid fossil fuel a. CO (or CEMS) 140 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (150 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 1.3E-01 lb per MMBtu of steam output or 1.5 lb per MWh; 3-run average 1 hr minimum sampling time.
7. Stokers/sloped grate/others designed to burn wet biomass fuel a. CO (or CEMS) 1,500 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (720 ppm by volume on a dry basis corrected to 3-percent oxygen, c 30-day rolling average) 1.4 lb per MMBtu of steam output or 17 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.7E-02 lb per MMBtu of heat input; or (2.4E-04 lb per MMBtu of heat input) 4.3E-02 lb per MMBtu of steam output or 5.2E-01 lb per MWh; or (2.8E-04 lb per MMBtu of steam output or 3.4E-04 lb per MWh) Collect a minimum of 2 dscm per run.
8. Stokers/sloped grate/others designed to burn kiln-dried biomass fuel a. CO 460 ppm by volume on a dry basis corrected to 3-percent oxygen 4.2E-01 lb per MMBtu of steam output or 5.1 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 3.2E-01 lb per MMBtu of heat input; or (4.0E-03 lb per MMBtu of heat input) 3.7E-01 lb per MMBtu of steam output or 4.5 lb per MWh; or (4.6E-03 lb per MMBtu of steam output or 5.6E-02 lb per MWh) Collect a minimum of 1 dscm per run.
9. Fluidized bed units designed to burn biomass/bio-based solid a. CO (or CEMS) 470 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (310 ppm by volume on a dry basis corrected to 3- percent oxygen, c 30-day rolling average) 4.6E-01 lb per MMBtu of steam output or 5.2 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 1.1E-01 lb per MMBtu of heat input; or (1.2E-03 lb per MMBtu of heat input) 1.4E-01 lb per MMBtu of steam output or 1.6 lb per MWh; or (1.5E-03 lb per MMBtu of steam output or 1.7E-02 lb per MWh) Collect a minimum of 1 dscm per run.
10. Suspension burners designed to burn biomass/bio-based solid a. CO (or CEMS) 2,400 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (2,000 ppm by volume on a dry basis corrected to 3-percent oxygen, c 10-day rolling average) 1.9 lb per MMBtu of steam output or 27 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 5.1E-02 lb per MMBtu of heat input; or (6.5E-03 lb per MMBtu of heat input) 5.2E-02 lb per MMBtu of steam output or 7.1E-01 lb per MWh; or (6.6E-03 lb per MMBtu of steam output or 9.1E-02 lb per MWh) Collect a minimum of 2 dscm per run.
11. Dutch Ovens/Pile burners designed to burn biomass/bio-based solid a. CO (or CEMS) 770 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (520 ppm by volume on a dry basis corrected to 3-percent oxygen, c 10-day rolling average) 8.4E-01 lb per MMBtu of steam output or 8.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.8E-01 lb per MMBtu of heat input; or (2.0E-03 lb per MMBtu of heat input) 3.9E-01 lb per MMBtu of steam output or 3.9 lb per MWh; or (2.8E-03 lb per MMBtu of steam output or 2.8E-02 lb per MWh) Collect a minimum of 1 dscm per run.
12. Fuel cell units designed to burn biomass/bio-based solid a. CO 1,100 ppm by volume on a dry basis corrected to 3-percent oxygen 2.4 lb per MMBtu of steam output or 12 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.0E-02 lb per MMBtu of heat input; or (5.8E-03 lb per MMBtu of heat input) 5.5E-02 lb per MMBtu of steam output or 2.8E-01 lb per MWh; or (1.6E-02 lb per MMBtu of steam output or 8.1E-02 lb per MWh) Collect a minimum of 2 dscm per run.
13. Hybrid suspension grate units designed to burn biomass/bio-based solid a. CO (or CEMS) 3,500 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average; or (900 ppm by volume on a dry basis corrected to 3- percent oxygen, c 30-day rolling average) 3.5 lb per MMBtu of steam output or 39 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 4.4E-01 lb per MMBtu of heat input; or (4.5E-04 lb per MMBtu of heat input) 5.5E-01 lb per MMBtu of steam output or 6.2 lb per MWh; or (5.7E-04 lb per MMBtu of steam output or 6.3E-03 lb per MWh) Collect a minimum of 1 dscm per run.
14. Units designed to burn liquid fuel a. HCl 1.1E-03 lb per MMBtu of heat input 1.4E-03 lb per MMBtu of steam output or 1.6E-02 lb per MWh For M26A, collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
b. Mercury 2.0E-06 lb per MMBtu of heat input 2.5E-06 lb per MMBtu of steam output or 2.8E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B collect a minimum sample as specified in the method, for ASTM D6784 b collect a minimum of 2 dscm.
15. Units designed to burn heavy liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 6.2E-02 lb per MMBtu of heat input; or (2.0E-04 lb per MMBtu of heat input) 7.5E-02 lb per MMBtu of steam output or 8.6E-01 lb per MWh; or (2.5E-04 lb per MMBtu of steam output or 2.8E-03 lb per MWh) Collect a minimum of 1 dscm per run.
16. Units designed to burn light liquid fuel a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.13 lb per MMBtu of steam output or 1.4 lb per MWh 1 hr minimum sampling time.
b. Filterable PM (or TSM) 7.9E-03 lb per MMBtu of heat input; or (6.2E-05 lb per MMBtu of heat input) 9.6E-03 lb per MMBtu of steam output or 1.1E-01 lb per MWh; or (7.5E-05 lb per MMBtu of steam output or 8.6E-04 lb per MWh) Collect a minimum of 3 dscm per run.
17. Units designed to burn liquid fuel that are non-continental units a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen, 3-run average based on stack test 0.13 lb per MMBtu of steam output or 1.4 lb per MWh; 3-run average 1 hr minimum sampling time.
b. Filterable PM (or TSM) 2.7E-01 lb per MMBtu of heat input; or (8.6E-04 lb per MMBtu of heat input) 3.3E-01 lb per MMBtu of steam output or 3.8 lb per MWh; or (1.1E-03 lb per MMBtu of steam output or 1.2E-02 lb per MWh) Collect a minimum of 2 dscm per run.
18. Units designed to burn gas 2 (other) gases a. CO 130 ppm by volume on a dry basis corrected to 3-percent oxygen 0.16 lb per MMBtu of steam output or 1.0 lb per MWh 1 hr minimum sampling time.
b. HCl 1.7E-03 lb per MMBtu of heat input 2.9E-03 lb per MMBtu of steam output or 1.8E-02 lb per MWh For M26A, collect a minimum of 2 dscm per run; for M26, collect a minimum of 240 liters per run.
c. Mercury 7.9E-06 lb per MMBtu of heat input 1.4E-05 lb per MMBtu of steam output or 8.3E-05 lb per MWh For M29, collect a minimum of 3 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784 b collect a minimum of 2 dscm.
d. Filterable PM (or TSM) 6.7E-03 lb per MMBtu of heat input or (2.1E-04 lb per MMBtu of heat input) 1.2E-02 lb per MMBtu of steam output or 7.0E-02 lb per MWh; or (3.5E-04 lb per MMBtu of steam output or 2.2E-03 lb per MWh) Collect a minimum of three dscm per run.

[87 FR 60863, Oct. 6, 2022]

Source: 76 FR 15664, Mar. 21, 2011, unless otherwise noted.

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