Title 40—Protection of Environment--Volume 1
PART 63—NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS FOR SOURCE CATEGORIES
§ 63.7300   What are my operation and maintenance requirements?
(a) As required by § 63.7310(a) you must always operate and maintain your affected source, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at least to the levels required by this subpart.
(b) You must prepare and operate at all times according to a written operation and maintenance plan for the general operation and maintenance of new or existing by-product coke oven batteries. Each plan must address, at a minimum, the elements listed in paragraphs (b)(1) through (6) of this section.
(1) Frequency and method of recording underfiring gas parameters.
(2) Frequency and method of recording battery operating temperature, including measurement of individual flue and cross-wall temperatures.
(3) Procedures to prevent pushing an oven before it is fully coked.
(4) Procedures to prevent overcharging and undercharging of ovens, including measurement of coal moisture, coal bulk density, and procedures for determining volume of coal charged.
(5) Frequency and procedures for inspecting flues, burners, and nozzles.
(6) Schedule and procedures for the daily washing of baffles.
(c) You must prepare and operate at all times according to a written operation and maintenance plan for each capture system and control device applied to pushing emissions from a new or existing coke oven battery. Each plan must address at a minimum the elements in paragraphs (c)(1) through (4) of this section.
(1) Monthly inspections of the equipment that are important to the performance of the total capture system ( e.g., pressure sensors, dampers, and damper switches). This inspection must include observations of the physical appearance of the equipment ( e.g., presence of holes in ductwork or hoods, flow constrictions caused by dents or accumulated dust in ductwork, and fan erosion). In the event a defect or deficiency is found in the capture system (during a monthly inspection or between inspections), you must complete repairs within 30 days after the date that the defect or deficiency is discovered. If you determine that the repairs cannot be completed within 30 days, you must submit a written request for an extension of time to complete the repairs that must be received by the permitting authority not more than 20 days after the date that the defect or deficiency is discovered. The request must contain a description of the defect or deficiency, the steps needed and taken to correct the problem, the interim steps being taken to mitigate the emissions impact of the defect or deficiency, and a proposed schedule for completing the repairs. The request shall be deemed approved unless and until such time as the permitting authority notifies you that it objects to the request. The permitting authority may consider all relevant factors in deciding whether to approve or deny the request (including feasibility and safety). Each approved schedule must provide for completion of repairs as expeditiously as practicable, and the permitting authority may request modifications to the proposed schedule as part of the approval process.
(2) Preventative maintenance for each control device, including a preventative maintenance schedule that is consistent with the manufacturer's instructions for routine and long-term maintenance.
(3) Corrective action for all baghouses applied to pushing emissions. In the event a bag leak detection system alarm is triggered, you must initiate corrective action to determine the cause of the alarm within 1 hour of the alarm, initiate corrective action to correct the cause of the problem within 24 hours of the alarm, and complete the corrective action as soon as practicable. Actions may include, but are not limited to:
(i) Inspecting the baghouse for air leaks, torn or broken bags or filter media, or any other condition that may cause an increase in emissions.
(ii) Sealing off defective bags or filter media.
(iii) Replacing defective bags or filter media or otherwise repairing the control device.
(iv) Sealing off a defective baghouse compartment.
(v) Cleaning the bag leak detection system probe, or otherwise repairing the bag leak detection system.
(vi) Shutting down the process producing the particulate emissions.
(4) Beginning January 5, 2026, you must identify and implement a set of site-specific good combustion practices for each battery. These good combustion practices should correspond to your standard operating procedures for maintaining the proper and efficient combustion within battery waste heat flues. Good combustion practices include, but are not limited to, the elements listed in paragraphs (c)(4)(i) through (v) of this section.
(i) Proper operating conditions for each battery ( e.g., minimum combustion temperature, burner alignment, or proper fuel-air distribution/mixing).
(ii) Routine inspection and preventative maintenance and corresponding schedules of each battery.
(iii) Performance analyses of each battery.
(iv) Maintaining applicable operator logs.
(v) Maintaining applicable records to document compliance with each element.
§ 63.7310   What are my general requirements for complying with this subpart?
(a) You must be in compliance with the emission limitations, work practice standards, and operation and maintenance requirements in this subpart at all times. At all times, you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require further efforts to reduce emissions if levels required by the applicable standard have been achieved. Determination of whether a source is operating in compliance with operation and maintenance requirements will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source.
(b) During the period between the compliance date specified for your affected source in § 63.7283 and the date upon which continuous monitoring systems have been installed and certified and any applicable operating limits have been set, you must maintain a log detailing the operation and maintenance of the process and emissions control equipment.
§ 63.7320   By what date must I conduct performance tests or other initial compliance demonstrations?
(a) As required in § 63.7(a)(2), you must conduct a performance test to demonstrate compliance with each limit in:
(1) Section 63.7290(a) through (e) for emissions of particulate matter, mercury, total acid gases, HCN, and total PAH from a control device applied to pushing emissions that applies to you within 180 calendar days after the compliance date that is specified in § 63.7283.
(2) Section 63.7296(c) through (f) for emissions of particulate matter, mercury, total acid gases, and HCN from a battery stack that applies to you within 180 calendar days after the compliance date that is specified in § 63.7283.
(3) Section 63.7297(a) through (d) for emissions of mercury, particulate matter, total acid gases, and total PAH from a HNR HRSG main stack that applies to you within 180 calendar days after the compliance date that is specified in § 63.7283.
(4) Section 63.7298(a) through (e) for emissions of mercury, particulate matter, total acid gases, total PAH, and formaldehyde from a HNR HRSG bypass/waste heat stack that applies to you within 180 calendar days after the compliance date that is specified in § 63.7283.
(b) You must conduct performance tests to demonstrate compliance with the TDS limit or constituent limit for quench water in § 63.7295(a)(1) and each opacity limit in § 63.7297(a) for a by-product coke oven battery stack by the compliance date that is specified in § 63.7283.
(c) For each work practice standard and operation and maintenance requirement that applies to you, you must demonstrate initial compliance within 30 calendar days after the compliance date that is specified in § 63.7283.
(d) If you commenced construction or reconstruction between July 3, 2001 and April 14, 2003, you must demonstrate initial compliance with either the proposed emission limit or the promulgated emission limit no later than October 14, 2003, or no later than 180 calendar days after startup of the source, whichever is later, according to § 63.7(a)(2)(ix).
(e) If you commenced construction or reconstruction between July 3, 2001 and April 14, 2003, and you chose to comply with the proposed emission limit when demonstrating initial compliance, you must conduct a second performance test to demonstrate compliance with the promulgated emission limit by October 11, 2006, or after startup of the source, whichever is later, according to § 63.7(a)(2)(ix).
§ 63.7321   When must I conduct subsequent performance tests?
(a) For each control device subject to an emission limit for particulate matter in § 63.7290(a), you must conduct subsequent performance tests no less frequently than once every 5 years or at the beginning of each term of your title V operating permit, whichever is less.
(b) For each source subject to emission limits in §§ 63.7290(b) through (d), 63.7296(c) through (f), 63.7297(a) through (d), and 63.7298(a) through (e) for capture systems and control devices applied to pushing emissions, battery stacks, HNR HRSG main stacks, and HNR HRSG bypass/waste heat stacks sources, respectively, you must conduct subsequent performance tests once every five years.
§ 63.7322   What test methods and other procedures must I use to demonstrate initial compliance with the emission limits?
(a) You must conduct each performance test that applies to your affected source based on representative performance ( i.e., performance based on the entire range of normal operating conditions) of the affected source for the period being tested, according to the requirements in paragraph (b) through (g) of this section. Representative conditions exclude periods of startup and shutdown. You shall not conduct performance tests during periods of malfunction. You must record the process information that is necessary to document operating conditions during the test and include in such record an explanation to support that such conditions represent the entire range of normal operation, including operational conditions for maximum emission if such emissions are not expected during maximum production. You shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.
(b) To determine compliance with the emission limit for particulate matter from a control device applied to pushing emissions where a cokeside shed is the capture system, battery stack, HNR HRSG main stack, and HNR HRSG bypass/waste heat stack, follow the test methods and procedures in paragraphs (b)(1) and (2) of this section. To determine compliance with a process-weighted mass rate of particulate matter (lb/ton of coke) from a control device applied to pushing emissions where a cokeside shed is not used, follow the test methods and procedures in paragraphs (b)(1) through (4) of this section.
(1) Determine the concentration of particulate matter according to the following test methods in appendices A-1 through A-3 to 40 CFR part 60.
(i) Method 1 to select sampling port locations and the number of traverse points. Sampling sites must be located at the outlet of the control device and prior to any releases to the atmosphere.
(ii) Method 2, 2F, or 2G to determine the volumetric flow rate of the stack gas.
(iii) Method 3, 3A, or 3B to determine the dry molecular weight of the stack gas. You may also use as an alternative to Method 3B, the manual method (but not instrumental procedures) for measuring the oxygen, carbon dioxide, and carbon monoxide content of exhaust gas, ANSI/ASME PTC 19.10-1981 (incorporated by reference, see § 63.14).
(iv) Method 4 to determine the moisture content of the stack gas.
(v) Method 5 or 5D, as applicable, to determine the concentration of filterable particulate matter in the stack gas.
(2) Collect a minimum sample volume of 30 dry standard cubic feet of gas during each test run. Three valid test runs are needed to comprise a performance test. During each particulate matter test run to meet the emission limitations in § 63.7290, sample only during periods of actual pushing when the capture system fan and control device are engaged. For capture systems and control devices applied to pushing emissions each run must start at the beginning of a push and finish at the end of a push ( i.e., sample for an integral number of pushes).
(3) Determine the total combined weight in tons of coke pushed during the duration of each test run according to the procedures in your source test plan for calculating coke yield from the quantity of coal charged to an individual oven.
(4) Compute the process-weighted mass emissions (E p, PM ) for each test run using equation 1 to this paragraph (b)(4) as follows:
(c) To determine compliance with the emission limit for mercury from a control device applied to pushing emissions where a cokeside shed is the capture system, battery stack, HNR HRSG main stack, and HNR HRSG bypass/waste heat stack, follow the test methods and procedures in paragraphs (c)(1) and (2) of this section. To determine compliance with a process-weighted mass rate of mercury (lb/ton of coke) from a control device applied to pushing emissions and battery stack, follow the test methods and procedures in paragraphs (c)(1) through (4) of this section.
(1) Determine the concentration of mercury according to the following test methods.
(i) The methods specified in sections (b)(1)(i) through (iv) of this section.
(ii) Method 29 in appendix A-8 to 40 CFR part 60, to determine the concentration of mercury in the stack gas. The voluntary consensus standard ASTM D6784-16 (incorporated by reference, see § 63.14) is an acceptable alternative to EPA Method 29 (portion for mercury only) as a method for measuring mercury, note: applies to concentrations approximately 0.5—100 µg/Nm3.
(2) Collect a minimum sample volume of 70 dry standard cubic feet of gas during each mercury test run. Three valid test runs are needed to comprise a performance test. During each mercury test run to meet the emission limitations in § 63.7290, sample only during periods of actual pushing when the capture system fan and control device are engaged. For capture systems and control devices applied to pushing emissions each run must start at the beginning of a push and finish at the end of a push ( i.e., sample for an integral number of pushes).
(3) Determine the total combined weight in tons of coke pushed during the duration of each test run according to the procedures in your source test plan for calculating coke yield from the quantity of coal charged to an individual oven.
(4) Compute the process-weighted mass emissions (E p,Hg ) for each test run using equation 2 to this paragraph (c)(4) as follows:
(d) To determine compliance with the emission limit for total acid gases from a HNR HRSG main stack and HNR HRSG bypass/waste heat stack, follow the test methods and procedures in paragraphs (d)(1) and (2) of this section. To determine compliance with a process-weighted mass rate of total acid gases (lb/ton of coke) from a control device applied to pushing emissions and battery stack, follow the test methods and procedures in paragraphs (d)(1) through (4) of this section.
(1) Determine the concentration of total acid gases according to the following test methods.
(i) The methods specified in sections (b)(1)(i) through (iv) of this section.
(ii) Methods 26 or 26A in appendix A-8 to 40 CFR part 60, or Method 320 in appendix A to this part, to determine the concentration of total acid gases in the stack gas. The voluntary consensus standard ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14) is an acceptable alternative to Method 320 at this time with caveats requiring inclusion of selected annexes to the standard as mandatory. When using ASTM D6348-12 (Reapproved 2020), the following conditions must be met:
(A) The test plan preparation and implementation in the Annexes to ASTM D6348-12 (Reapproved 2020), Annexes A1 through A8 are mandatory; and
(B) In ASTM D6348-12 (Reapproved2020) Annex A5 (Analyte Spiking Technique), the percent (%) R must be determined for each target analyte (Equation A5.5).
(C) In order for the test data to be acceptable for a compound, % R must be greater than or equal to 70% and less than or equal to 130%. If the % R value does not meet this criterion for a target compound, the test data is not acceptable for that compound and the test must be repeated for that analyte ( i.e., the sampling and/or analytical procedure should be adjusted before a retest). The % R value for each compound must be reported in the test report, and all field measurements must be corrected with the calculated % R value for that compound by using equation 3 to this paragraph (d)((1)(ii)(C):
(2) Collect a minimum sample volume of 35 dry standard cubic feet of gas during each test run for Method 26 and 26A in appendix A-8 to 40 CFR part 60. For Method 320 in appendix A to this part and ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14), each test run must be a minimum of one hour in duration. Three valid test runs are needed to comprise a performance test. During each total acid gases test run to meet the emission limitations in § 63.7290, sample only during periods of pushing when the capture system fan and control device are engaged. For capture systems and control devices applied to pushing emissions each run must start at the beginning of a push and finish at the end of a push ( i.e., sample for an integral number of pushes).
(3) Determine the total combined weight in tons of coke pushed during the duration of each test run according to the procedures in your source test plan for calculating coke yield from the quantity of coal charged to an individual oven.
(4) Compute the process-weighted mass emissions (E p,AG ) for each test run using equation 4 to this paragraph (d)(4) as follows:
(e) To determine compliance with a process-weighted mass rate of hydrogen cyanide (lb/ton of coke) from a control device applied to pushing emissions and battery stack, follow the test methods and procedures in paragraphs (e)(1) through (4) of this section.
(1) Determine the concentration of hydrogen cyanide according to the following test methods.
(i) The methods specified in sections (b)(1)(i) through (iv) of this section.
(ii) Method 320 in appendix A to this part, to determine the concentration of hydrogen cyanide in the stack gas. The voluntary consensus standard ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14) is an acceptable alternative to Method 320 at this time with caveats requiring inclusion of selected annexes to the standard as mandatory. When using ASTM D6348-12 (Reapproved 2020), the following conditions must be met:
(A) The test plan preparation and implementation in the Annexes to ASTM D6348-12 (Reapproved 2020), Annexes A1 through A8 are mandatory; and
(B) In ASTM D6348-12 (Reapproved 2020) Annex A5 (Analyte Spiking Technique), the percent (%) R must be determined for each target analyte (Equation A5.5).
(C) In order for the test data to be acceptable for a compound, % R must be greater than or equal to 70% and less than or equal to 130%. If the % R value does not meet this criterion for a target compound, the test data is not acceptable for that compound and the test must be repeated for that analyte ( i.e., the sampling and/or analytical procedure should be adjusted before a retest). The % R value for each compound must be reported in the test report, and all field measurements must be corrected with the calculated % R value for that compound by using equation 5 to this paragraph (e)(1)(ii)(C):
(2) Collect a minimum of eight spectra for each of six runs (or hours) evenly spaced over the test period for Method 320 in appendix A to this part or alternatively ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14). Three valid test runs are needed to comprise a performance test. During each hydrogen cyanide test run to meet the emission limitations in § 63.7290, sample only during periods of actual pushing when the capture system fan and control device are engaged. For capture systems and control devices applied to pushing emissions each run must start at the beginning of a push and finish at the end of a push ( i.e., sample for an integral number of pushes).
(3) Determine the total combined weight in tons of coke pushed during the duration of each test run according to the procedures in your source test plan for calculating coke yield from the quantity of coal charged to an individual oven.
(4) Compute the process-weighted mass emissions (E p,HCN ) for each test run using equation 6 to this paragraph (e)(4) as follows:
(f) To determine compliance with the emission limit for total PAH from a HNR HRSG main stack and HNR HRSG bypass/waste heat stack, follow the test methods and procedures in paragraphs (f)(1) and (2) of this section. To determine compliance with a process-weighted mass rate of total PAH (lb/ton of coke) from a control device applied to pushing emissions, follow the test methods and procedures in paragraphs (f)(1) through (4) of this section.
(1) Determine the concentration of total PAH, the sum of 17 PAH compounds listed at § 63.7290(e), according to the following test methods.
(i) The methods specified in sections (b)(1)(i) through (iv) of this section.
(ii) Method 23 in appendix A-7 to 40 CFR part 60, to determine the concentration of total PAH in the stack gas.
(2) Collect a minimum sample volume of 105 dry standard cubic feet of gas during each test run for total PAH. Three valid test runs are needed to comprise a performance test. During each total PAH test run to meet the emission limitations in § 63.7290, sample only during periods of actual pushing when the capture system fan and control device are engaged. For capture systems and control devices applied to pushing emissions each run must start at the beginning of a push and finish at the end of a push ( i.e., sample for an integral number of pushes). When calculating total PAH, the estimated level of detection (EDL) shall be used for each PAH measured below the EDL.
(3) Determine the total combined weight in tons of coke pushed during the duration of each test run according to the procedures in your source test plan for calculating coke yield from the quantity of coal charged to an individual oven.
(4) Compute the process-weighted mass emissions (E p,PAH ) for each test run using equation 7 to this paragraph (f)(4) as follows:
(g) To determine compliance with the emission limit for formaldehyde from a HNR HRSG bypass/waste heat stack, follow the test methods and procedures in paragraphs (h)(1) and (2) of this section.
(1) Determine the concentration of formaldehyde according to the following test methods.
(i) The methods specified in sections (b)(1)(i) through (iv) of this section.
(ii) Method 316 or Method 320 in appendix A to this part, to determine the concentration of formaldehyde in the stack gas. The voluntary consensus standard ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14) is an acceptable alternative to Method 320 at this time with caveats requiring inclusion of selected annexes to the standard as mandatory. When using ASTM D6348-12 (Reapproved 2020), the following conditions must be met:
(A) The test plan preparation and implementation in the Annexes to ASTM D6348-12 (Reapproved 2020), Annexes A1 through A8 are mandatory; and
(B) In ASTM D6348-12 (Reapproved 2020) Annex A5 (Analyte Spiking Technique), the percent (%) R must be determined for each target analyte (Equation A5.5).
(C) In order for the test data to be acceptable for a compound, % R must be greater than or equal to 70% and less than or equal to 130%. If the % R value does not meet this criterion for a target compound, the test data is not acceptable for that compound and the test must be repeated for that analyte ( i.e., the sampling and/or analytical procedure should be adjusted before a retest). The % R value for each compound must be reported in the test report, and all field measurements must be corrected with the calculated % R value for that compound by using equation 8 to this paragraph (g)(1)(ii)(C):
(2) Sample time should ensure that minimum quantification levels have been met under the methods used during each test run, for Method 320 in appendix A to this part or ASTM D6348-12 (Reapproved 2020) (incorporated by reference, see § 63.14), each test run must be at least one hour in duration. Three valid test runs are needed to comprise a performance test.
§ 63.7323   What procedures must I use to establish operating limits?
(a) For a venturi scrubber applied to pushing emissions from a coke oven battery, you must establish site-specific operating limits for pressure drop and scrubber water flow rate according to the procedures in paragraphs (a)(1) and (2) of this section.
(1) Using the continuous parameter monitoring systems (CPMS) required in § 63.7330(b), measure and record the pressure drop and scrubber water flow rate for each particulate matter test run during periods of pushing. A minimum of one pressure drop measurement and one scrubber water flow rate measurement must be obtained for each push.
(2) Compute and record the average pressure drop and scrubber water flow rate for each test run. Your operating limits are the lowest average pressure drop and scrubber water flow rate values recorded during any of the three runs that meet the applicable emission limit.
(b) For a hot water scrubber applied to pushing emissions from a coke oven battery, you must establish site-specific operating limits for water pressure and water temperature according to the procedures in paragraphs (b)(1) and (2) of this section.
(1) Using the CPMS required in § 63.7330(c), measure and record the hot water pressure and temperature for each particulate matter test run during periods of pushing. A minimum of one pressure measurement and one temperature measurement must be made just prior to each push by monitoring the hot water holding tank on the mobile scrubber car.
(2) Compute and record the average water pressure and temperature for each test run. Your operating limits are the lowest pressure and temperature values recorded during any of the three runs that meet the applicable emission limit.
(c) For a capture system applied to pushing emissions from a coke oven battery, you must establish a site-specific operating limit according to the procedures in paragraphs (c)(1), (2), or (3) of this section.
(1) If you elect the operating limit in § 63.7290(f)(3) for volumetric flow rate, measure and record the total volumetric flow rate at the inlet of the control device during each push sampled for each particulate matter test run. Your operating limit is the lowest volumetric flow rate recorded during any of the three runs that meet the emission limit.
(2) If you elect the operating limit in § 63.7290(f)(3)(i) for fan motor amperes, measure and record the fan motor amperes during each push sampled for each particulate matter test run. Your operating limit is the lowest fan motor amperes recorded during any of the three runs that meet the emission limit.
(3) If you elect the operating limit in § 63.7290(f)(3)(ii) for static pressure or fan RPM, measure and record the static pressure at the inlet of the control device or fan RPM during each push sampled for each particulate matter test run. Your operating limit for static pressure is the minimum vacuum recorded during any of the three runs that meets the emission limit. Your operating limit for fan RPM is the lowest fan RPM recorded during any of the three runs that meets the emission limit.
(d) For a multicyclone applied to pushing emissions from a coke oven battery, you must establish a site-specific operating limit for pressure drop according to the procedures in paragraphs (d)(1) and (2) of this section.
(1) Using the CPMS required in § 63.7330(f), measure and record the pressure drop for each particulate matter test run during periods of pushing. A minimum of one pressure drop measurement must be obtained for each push.
(2) Compute and record the average pressure drop for each test run. Your operating limit is the highest average pressure drop value recorded during any of the three runs that meet the emission limit.
(e) You may change the operating limit for a venturi scrubber, capture system, or mobile control device that captures emissions during pushing if you meet the requirements in paragraphs (e)(1) through (3) of this section.
(1) Submit a written notification to the Administrator of your request to conduct a new performance test to revise the operating limit.
(2) Conduct a performance test to demonstrate that emissions of particulate matter from the control device do not exceed the applicable limit in § 63.7290(a).
(3) Establish revised operating limits according to the applicable procedures in paragraphs (a) through (d) of this section.
§ 63.7324   What procedures must I use to demonstrate initial compliance with the opacity limits?
(a) You must conduct each performance test that applies to your affected source based on representative performance ( i.e., performance based on the entire range of normal operating conditions) of the affected source for the period being tested, according to the requirements in paragraph (b) of this section. Representative conditions exclude periods of startup and shutdown. You shall not conduct performance tests during periods of malfunction. You must record the process information that is necessary to document operating conditions during the test and include in such record an explanation to support that such conditions represent the entire range of normal operation, including operational conditions for maximum emissions if such emissions are not expected during maximum production. You shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.
(b) To determine compliance with the daily average opacity limit for stacks of 15 percent for a by-product coke oven battery on a normal coking cycle or 20 percent for a by-product coke oven battery on batterywide extended coking, follow the test methods and procedures in paragraphs (b)(1) through (3) of this section.
(1) Using the continuous opacity monitoring system (COMS) required in § 63.7330(e), measure and record the opacity of emissions from each battery stack for a 24-hour period.
(2) Reduce the monitoring data to hourly averages as specified in § 63.8(g)(2).
(3) Compute and record the 24-hour (daily) average of the COMS data.
§ 63.7325   What test methods and other procedures must I use to demonstrate initial compliance with the TDS or constituent limits for quench water?
(a) If you elect the TDS limit for quench water in § 63.7295(a)(1)(i), you must conduct each performance test that applies to your affected source based on representative performance ( i.e., performance based on the entire range of normal operating conditions) of the affected source for the period being tested, according to the conditions in paragraphs (a)(1) and (2) of this section. Representative conditions exclude periods of startup and shutdown. You shall not conduct performance tests during periods of malfunction. You must record the process information that is necessary to document operating conditions during the test and include in such record an explanation to support that such conditions represent the entire range of normal operation, including operational conditions for maximum emissions if such emissions are not expected during maximum production. You shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.
(1) Take the quench water sample from a location that provides a representative sample of the quench water as applied to the coke ( e.g., from the header that feeds water to the quench tower reservoirs). Conduct sampling under normal and representative operating conditions.
(2) Determine the TDS concentration of the sample using Method 160.1 in 40 CFR part 136.3 (see “residue—filterable”), except that you must dry the total filterable residue at 103 to 105 °C (degrees Centigrade) instead of 180 °C.
(b) If at any time you elect to meet the alternative requirements for quench water in § 63.7295(a)(1)(ii), you must establish a site-specific constituent limit according to the procedures in paragraphs (b)(1) through (4) of this section.
(1) Take a minimum of nine quench water samples from a location that provides a representative sample of the quench water as applied to the coke ( e.g., from the header that feeds water to the quench tower reservoirs). Conduct sampling under normal and representative operating conditions.
(2) For each sample, determine the TDS concentration according to the requirements in paragraph (a)(2) of this section and the concentration of benzene, benzo(a)pyrene, and naphthalene using the applicable methods in 40 CFR part 136 or an approved alternative method.
(3) Determine and record the highest sum of the concentrations of benzene, benzo(a)pyrene, and naphthalene in any sample that has a TDS concentration less than or equal to the TDS limit of 1,100 mg/L. This concentration is the site-specific constituent limit.
(4) Submit the site-specific limit, sampling results, and all supporting data and calculations to your permitting authority for review and approval.
(c) If you elect the constituent limit for quench water in § 63.7295(a)(1)(ii), you must conduct each performance test that applies to your affected source according to the conditions in paragraphs (c)(1) and (2) of this section.
(1) Take a quench water sample from a location that provides a representative sample of the quench water as applied to the coke ( e.g., from the header that feeds water to the quench tower reservoirs). Conduct sampling under normal and representative operating conditions.
(2) Determine the sum of the concentration of benzene, benzo(a)pyrene, and naphthalene in the sample using the applicable methods in 40 CFR part 136 or an approved alternative method.
§ 63.7326   How do I demonstrate initial compliance with the emission limitations that apply to me?
(a) For each coke oven battery subject to the emission limits from a control device applied to pushing emissions, you have demonstrated initial compliance if you meet the requirements in paragraphs (a)(1) through (9) of this section that apply to you.
(1) The concentration of particulate matter, measured in accordance with the performance test procedures in § 63.7322(b)(1) and (2), did not exceed 0.01 gr/dscf for a control device where a cokeside shed is used to capture pushing emissions or the process-weighted mass rate of particulate matter (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(b)(1) through (4), did not exceed:
(i) 0.02 lb/ton of coke if a moveable hood vented to a stationary control device is used to capture emissions;
(ii) If a mobile scrubber car that does not capture emissions during travel is used, 0.03 lb/ton of coke from a control device applied to pushing emissions from a short coke oven battery or 0.01 lb/ton of coke from a control device applied to pushing emissions from a tall coke oven battery; and
(iii) 0.04 lb/ton of coke if a mobile control device that captures emissions during travel is used.
(2) The process-weighted mass rate of mercury (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(c)(1) through (4), did not exceed 3.4E-07 lb/ton coke for pushing emissions from a new coke oven battery or 8.9E-07 lb/ton coke for pushing emissions from an existing coke oven battery.
(3) The process-weighted mass rate of total acid gases, the sum of hydrochloric acid and hydrofluoric acid (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(d)(1) through (4), did not exceed 5.1E-04 lb/ton coke for pushing emissions from a new coke oven battery or 0.0052 lb/ton coke for pushing emissions from an existing coke oven battery.
(4) The process-weighted mass rate of hydrogen cyanide (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(e)(1) through (4), did not exceed 3.8E-05 lb/ton coke for pushing emissions from a new coke oven battery or 0.0011 lb/ton coke for pushing emissions from an existing coke oven battery.
(5) The process-weighted mass rate of total PAH (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(f)(1) through (4), did not exceed 1.4E-05 lb/ton coke for pushing emissions from a new coke oven battery or 3.4E-04 lb/ton coke for pushing emissions from an existing coke oven battery.
(6) For each venturi scrubber applied to pushing emissions, you have established appropriate site-specific operating limits and have a record of the pressure drop and scrubber water flow rate measured during the performance test in accordance with § 63.7323(a).
(7) For each hot water scrubber applied to pushing emissions, you have established appropriate site-specific operating limits and have a record of the water pressure and temperature measured during the performance test in accordance with § 63.7323(b).
(8) For each capture system applied to pushing emissions, you have established an appropriate site-specific operating limit, and:
(i) If you elect the operating limit in § 63.7290(f)(3) for volumetric flow rate, you have a record of the total volumetric flow rate at the inlet of the control device measured during the performance test in accordance with § 63.7323(c)(1); or
(ii) If you elect the operating limit in § 63.7290(f)(3)(i) for fan motor amperes, you have a record of the fan motor amperes during the performance test in accordance with § 63.7323(c)(2); or
(iii) If you elect the operating limit in § 63.7290(f)(3)(ii) for static pressure or fan RPM, you have a record of the static pressure at the inlet of the control device or fan RPM measured during the performance test in accordance with § 63.7323(c)(3).
(9) For each multicyclone applied to pushing emissions, you have established an appropriate site-specific operating limit and have a record of the pressure drop measured during the performance test in accordance with § 63.7323(d).
(b) For each new or existing by-product coke oven battery subject to the emission limits in § 63.7296, you have demonstrated initial compliance if you meet the requirements in paragraphs (b)(1) through (5) of this section.
(1) The opacity limit for stacks in § 63.7296(a), you have demonstrated initial compliance if the daily average opacity, as measured according to the performance test procedures in § 63.7324(b), is no more than 15 percent for a battery on a normal coking cycle or 20 percent for a battery on batterywide extended coking.
(2) The concentration of particulate matter, measured in accordance with the performance test procedures in § 63.7322(b)(1) and (2), did not exceed 0.013 gr/dscf at 10 percent oxygen from a battery stack at a new by-product coke oven battery or 0.13 gr/dscf at 10 percent oxygen from a battery stack at an existing by-product coke oven battery.
(3) The process-weighted mass rate of mercury (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(c)(1) through (4), did not exceed 7.1E-06 lb/ton coke from a battery stack at a new by-product coke oven battery or 4.5E-05 lb/ton coke from a battery stack at an existing by-product coke oven battery.
(4) The process-weighted mass rate of total acid gases (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(d)(1) through (4), did not exceed 0.013 lb/ton coke from a battery stack at a new by-product coke oven battery or 0.16 lb/ton coke from a battery stack at an existing by-product coke oven battery.
(5) The process-weighted mass rate of hydrogen cyanide (lb/ton of coke), measured in accordance with the performance test procedures in § 63.7322(e)(1) through (4), did not exceed 7.4E-04 lb/ton coke from a battery stack at a new by-product coke oven battery or 0.032 lb/ton coke from a battery stack at an existing by-product coke oven battery.
(c) For each new or existing by-product coke oven battery subject to the TDS limit or constituent limits for quench water in § 63.7295(a)(1),
(1) You have demonstrated initial compliance with the TDS limit in § 63.7295(a)(1)(i) if the TDS concentration, as measured according to the performance test procedures in § 63.7325(a), does not exceed 1,100 mg/L.
(2) You have demonstrated initial compliance with the constituent limit in § 63.7295(a)(1)(ii) if:
(i) You have established a site-specific constituent limit according to the procedures in § 63.7325(b); and
(ii) The sum of the constituent concentrations, as measured according to the performance test procedures in § 63.7325(c), is less than or equal to the site-specific limit.
(d) For each new or existing HNR HRSG main stack subject to the emission limits in § 63.7297, you have demonstrated initial compliance if you meet the requirements in paragraphs (d)(1) through (4) of this section.
(1) The concentration of particulate matter, measured in accordance with the performance test procedures in § 63.7322(b)(1) and (2), did not exceed 8.8E-04 gr/dscf at 10 percent oxygen from a HNR HRSG main stack at a new HNR coke battery or 0.0049 gr/dscf at 10 percent oxygen at a HNR HRSG main stack at an existing HNR coke oven battery.
(2) The concentration of mercury, measured in accordance with the performance test procedures in § 63.7322(c)(1) and (2), did not exceed 1.5E-06 gr/dscf at 10 percent oxygen from a HNR HRSG main stack at a new HNR coke battery or 3.0E-06 gr/dscf at 10 percent oxygen at a HNR HRSG main stack at an existing HNR HRSG.
(3) The concentration of total acid gases, measured in accordance with the performance test procedures in § 63.7322(d)(1) and (2), did not exceed 3.4E-03 gr/dscf at 10 percent oxygen from a HNR HRSG main stack at a new coke oven battery or 4.9E-02 gr/dscf at 10 percent oxygen at a HNR HRSG main stack at an existing HNR coke oven battery.
(4) The concentration of total PAHs, measured in accordance with the performance test procedures in § 63.7322(f)(1) and (2), did not exceed 4.7E-07 gr/dscf at 10 percent oxygen from a HNR HRSG main stack at a new coke oven battery or 4.8E-07 gr/dscf at 10 percent oxygen at a HNR HRSG main stack at an existing HNR coke oven battery.
(e) For each HNR HRSG bypass/waste heat stack through which emissions are discharged from a new or existing coke oven battery subject to the emission limits in § 63.7298, you have demonstrated initial compliance if you meet the requirements in paragraphs (e)(1) through (5) of this section.
(1) The concentration of particulate matter, measured in accordance with the performance test procedures in § 63.7322(b)(1) and (2), did not exceed 0.022 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at a new HNR coke oven battery or 0.032 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at an existing HNR coke oven battery.
(2) The concentration of mercury, measured in accordance with the performance test procedures in § 63.7322(c)(1) and (2), did not exceed 8.6E-06 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at a new HNR coke oven battery or 1.2E-05 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at an existing HNR coke battery.
(3) The concentration of total acid gases, measured in accordance with the performance test procedures in § 63.7322(d)(1) and (2), did not exceed 0.12 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at a new HNR coke oven battery or 0.095 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at an existing HNR coke oven battery.
(4) The concentration of total PAHs, measured in accordance with the performance test procedures in § 63.7322(f)(1) and (2), did not exceed 2.7E-06 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at a new coke oven battery or existing HNR coke oven battery.
(5) The concentration of formaldehyde, measured in accordance with the performance test procedures in § 63.7322(g)(1) and (2), did not exceed 1.8E-05 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at a new HNR coke oven battery or 0.0012 gr/dscf at 10 percent oxygen from a HNR HRSG bypass/waste heat stack at an existing HNR coke oven battery.
(f) For each by-product coke oven battery stack subject to an opacity limit in § 63.7296(a) and each by-product coke oven battery subject to the requirements for quench water in § 63.7295(a)(1), you must submit a notification of compliance status containing the results of the COMS performance test for battery stacks and the quench water performance test (TDS or constituent limit) according to § 63.7340(e)(1). For each particulate matter, mercury, total acid gases, hydrogen cyanide, total PAHs, or formaldehyde emission limitation that applies to you, you must submit a notification of compliance status containing a summary of the results of the performance test according to § 63.7340(e)(2).
§ 63.7327   How do I demonstrate initial compliance with the work practice standards that apply to me?
(a) For each by-product coke oven battery with vertical flues subject to the work practice standards for fugitive pushing emissions in § 63.7291(a), you have demonstrated initial compliance if you certify in your notification of compliance status that you will meet each of the work practice requirements beginning no later than the compliance date that is specified in § 63.7283.
(b) For each by-product coke oven battery with horizontal flues subject to the work practice standards for fugitive pushing emissions in § 63.7292(a), you have demonstrated initial compliance if you have met the requirements of paragraphs (b)(1) and (2) of this section:
(1) You have prepared and submitted a written plan and supporting documentation establishing appropriate minimum flue temperatures for different coking times and the lowest acceptable temperature to the Administrator (or delegated authority) for review and approval; and
(2) You certify in your notification of compliance status that you will meet each of the work practice requirements beginning no later than the compliance date that is specified in § 63.7283.
(c) For each nonrecovery coke oven battery subject to the work practice standards for fugitive pushing emissions in § 63.7293(a), you have demonstrated initial compliance if you certify in your notification of compliance status that you will meet each of the work practice requirements beginning no later than the compliance date that is specified in § 63.7283.
(d) For each by-product coke oven battery subject to the work practice standards for soaking in § 63.7294, you have demonstrated initial compliance if you have met the requirements of paragraphs (d)(1) and (2) of this section:
(1) You have prepared and submitted a written work practice plan in accordance with § 63.7294(a); and
(2) You certify in your notification of compliance status that you will meet each of the work practice requirements beginning no later than the compliance date that is specified in § 63.7283.
(e) For each coke oven battery, you have demonstrated initial compliance with the work practice standards for quenching in § 63.7295(b) if you certify in your notification of compliance status that you have met the requirements of paragraphs (e)(1) and (2) of this section:
(1) You have installed the required equipment in each quench tower; and
(2) You will meet each of the work practice requirements beginning no later than the compliance date that is specified in § 63.7283.
(f) For each work practice standard that applies to you, you must submit a notification of compliance status according to the requirements in § 63.7340(e)(1).
§ 63.7328   How do I demonstrate initial compliance with the operation and maintenance requirements that apply to me?
You have demonstrated initial compliance if you certify in your notification of compliance status that you have met the requirements of paragraphs (a) through (d) of this section:
(a) You have prepared the operation and maintenance plans according to the requirements in § 63.7300(b) and (c);
(b) You will operate each by-product coke oven battery and each capture system and control device applied to pushing emissions from a coke oven battery according to the procedures in the plans beginning no later than the compliance date that is specified in § 63.7283;
(c) You have prepared a site-specific monitoring plan according to the requirements in § 63.7331(b); and
(d) You submit a notification of compliance status according to the requirements in § 63.7340(e).
§ 63.7330   What are my monitoring requirements?
(a) For each baghouse applied to pushing emissions from a coke oven battery, you must at all times monitor the relative change in particulate matter loadings using a bag leak detection system according to the requirements in § 63.7331(a) and conduct inspections at their specified frequency according to the requirements in paragraphs (a)(1) through (8) of this section.
(1) Monitor the pressure drop across each baghouse cell each day to ensure pressure drop is within the normal operating range identified in the manual;
(2) Confirm that dust is being removed from hoppers through weekly visual inspections or equivalent means of ensuring the proper functioning of removal mechanisms;
(3) Check the compressed air supply for pulse-jet baghouses each day;
(4) Monitor cleaning cycles to ensure proper operation using an appropriate methodology;
(5) Check bag cleaning mechanisms for proper functioning through monthly visual inspection or equivalent means;
(6) Make monthly visual checks of bag tension on reverse air and shaker-type baghouses to ensure that bags are not kinked (kneed or bent) or laying on their sides. You do not have to make this check for shaker-type baghouses using self-tensioning (spring-loaded) devices;
(7) Confirm the physical integrity of the baghouse through quarterly visual inspections of the baghouse interior for air leaks; and
(8) Inspect fans for wear, material buildup, and corrosion through quarterly visual inspections, vibration detectors, or equivalent means.
(b) For each venturi scrubber applied to pushing emissions, you must at all times monitor the pressure drop and water flow rate using a CPMS according to the requirements in § 63.7331(e).
(c) For each hot water scrubber applied to pushing emissions, you must at all times monitor the water pressure and temperature using a CPMS according to the requirements in § 63.7331(f).
(d) For each capture system applied to pushing emissions, you must at all times monitor the volumetric flow rate according to the requirements in § 63.7331(g), the fan motor amperes according to the requirements in § 63.7331(h), or the static pressure or the fan RPM according to the requirements in § 63.7331(i).
(e) For each by-product coke oven battery, you must monitor at all times the opacity of emissions exiting each stack using a COMS according to the requirements in § 63.7331(j).
(f) For each multicyclone applied to pushing emissions, you must monitor at all times the pressure drop using a CPMS according to the requirements in § 63.7331(k).
§ 63.7331   What are the installation, operation, and maintenance requirements for my monitors?
(a) For each baghouse applied to pushing emissions, you must install, operate, and maintain each bag leak detection system according to the requirements in paragraphs (a)(1) through (7) of this section.
(1) The system must be certified by the manufacturer to be capable of detecting emissions of particulate matter at concentrations of 10 milligrams per actual cubic meter (0.0044 grains per actual cubic foot) or less;
(2) The system must provide output of relative changes in particulate matter loadings;
(3) The system must be equipped with an alarm that will sound when an increase in relative particulate loadings is detected over a preset level. The alarm must be located such that it can be heard by the appropriate plant personnel;
(4) Each system that works based on the triboelectric effect must be installed, operated, and maintained in a manner consistent with the guidance document, “Fabric Filter Bag Leak Detection Guidance” (EPA-454/R-98-015, September 1997). You may install, operate, and maintain other types of bag leak detection systems in a manner consistent with the manufacturer's written specifications and recommendations;
(5) To make the initial adjustment of the system, establish the baseline output by adjusting the sensitivity (range) and the averaging period of the device. Then, establish the alarm set points and the alarm delay time;
(6) Following the initial adjustment, do not adjust the sensitivity or range, averaging period, alarm set points, or alarm delay time, except as detailed in your operation and maintenance plan. Do not increase the sensitivity by more than 100 percent or decrease the sensitivity by more than 50 percent over a 365-day period unless a responsible official certifies, in writing, that the baghouse has been inspected and found to be in good operating condition; and
(7) Where multiple detectors are required, the system's instrumentation and alarm may be shared among detectors.
(b) For each CPMS required in § 63.7330, you must develop and make available for inspection upon request by the permitting authority a site-specific monitoring plan that addresses the requirements in paragraphs (b)(1) through (6) of this section.
(1) Installation of the CPMS sampling probe or other interface at a measurement location relative to each affected process unit such that the measurement is representative of control of the exhaust emissions ( e.g., on or downstream of the last control device);
(2) Performance and equipment specifications for the sample interface, the parametric signal analyzer, and the data collection and reduction system;
(3) Performance evaluation procedures and acceptance criteria ( e.g., calibrations);
(4) Ongoing operation and maintenance procedures in accordance with the general requirements of § 63.8(c)(1)(ii), (3), (4)(ii), (7), and (8);
(5) Ongoing data quality assurance procedures in accordance with the general requirements of §§ 63.8(d)(1) and (2) and 63.7342(b)(3); and
(6) Ongoing recordkeeping and reporting procedures in accordance the general requirements of § 63.10(c)(1) through (14) and (e)(1) and (2)(i).
(c) You must conduct a performance evaluation of each CPMS in accordance with your site-specific monitoring plan.
(d) You must operate and maintain the CPMS in continuous operation according to the site-specific monitoring plan.
(e) For each venturi scrubber applied to pushing emissions, you must install, operate, and maintain CPMS to measure and record the pressure drop across the scrubber and scrubber water flow rate during each push according to the requirements in paragraphs (b) through (d) of this section except as specified in paragraphs (e)(1) through (3) of this section.
(1) Each CPMS must complete a measurement at least once per push;
(2) Each CPMS must produce valid data for all pushes; and
(3) Each CPMS must determine and record the daily (24-hour) average of all recorded readings.
(f) For each hot water scrubber applied to pushing emissions, you must install, operate, and maintain CPMS to measure and record the water pressure and temperature during each push according to the requirements in paragraphs (b) through (d) of this section, except as specified in paragraphs (e)(1) through (3) of this section.
(g) If you elect the operating limit in § 63.7290(f)(3) for a capture system applied to pushing emissions, you must install, operate, and maintain a device to measure the total volumetric flow rate at the inlet of the control device.
(h) If you elect the operating limit in § 63.7290(f)(3)(i) for a capture system applied to pushing emissions, you must install, operate, and maintain a device to measure the fan motor amperes.
(i) If you elect the operating limit in § 63.7290(f)(3)(ii) for a capture system applied to pushing emissions, you must install, operate and maintain a device to measure static pressure at the inlet of the control device or the fan RPM.
(j) For each by-product coke oven battery, you must install, operate, and maintain a COMS to measure and record the opacity of emissions exiting each stack according to the requirements in paragraphs (j)(1) through (5) of this section.
(1) You must install, operate, and maintain each COMS according to the requirements in § 63.8(e) and Performance Specification 1 in 40 CFR part 60, appendix B. Identify periods the COMS is out-of-control, including any periods that the COMS fails to pass a daily calibration drift assessment, quarterly performance audit, or annual zero alignment audit.
(2) You must conduct a performance evaluation of each COMS according to the requirements in § 63.8 and Performance Specification 1 in appendix B to 40 CFR part 60;
(3) You must develop and implement a quality control program for operating and maintaining each COMS according to the requirements in § 63.8(d). At minimum, the quality control program must include a daily calibration drift assessment, quarterly performance audit, and an annual zero alignment audit of each COMS;
(4) Each COMS must complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period. You must reduce the COMS data as specified in § 63.8(g)(2).
(5) You must determine and record the hourly and daily (24-hour) average opacity according to the procedures in § 63.7324(b) using all the 6-minute averages collected for periods during which the COMS is not out-of-control.
(k) For each multicyclone applied to pushing emissions, you must install, operate, and maintain CPMS to measure and record the pressure drop across each multicyclone during each push according to the requirements in paragraphs (b) through (d) of this section except as specified in paragraphs (e)(1) through (3) of this section.
§ 63.7332   How do I monitor and collect data to demonstrate continuous compliance?
(a) Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including as applicable, calibration checks and required zero and span adjustments), you must monitor continuously (or collect data at all required intervals) at all times the affected source is operating.
(b) You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels, or in fulfilling a minimum data availability requirement, if applicable. You must use all the data collected during all other periods in assessing compliance. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitor to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions.
§ 63.7333   How do I demonstrate continuous compliance with the emission limitations that apply to me?
(a) For each control device applied to pushing emissions and subject to the emission limit in § 63.7290(a), you must demonstrate continuous compliance by meeting the requirements in paragraphs (a)(1) and (2) of this section:
(1) Maintaining emissions of particulate matter at or below the applicable limits in paragraphs § 63.7290(a)(1) through (4); and
(2) Conducting subsequent performance tests to demonstrate continuous compliance no less frequently than at the beginning of your title V operating permit or every 5 years, whichever is less.
(b) For each control device applied to pushing emissions and subject to the emission limits in § 63.7290(b) through (e), you must demonstrate continuous compliance by meeting the requirements in paragraphs (b)(1) through (5) of this section:
(1) Maintaining emissions of mercury at or below the applicable limits in § 63.7290(b);
(2) Maintaining emissions of total acid gases at or below the applicable limits in § 63.7290(c);
(3) Maintaining emissions of hydrogen cyanide at or below the applicable limits in § 63.7290(d);
(4) Maintaining emissions of total PAHs at or below the applicable limits in § 63.7290(e); and
(5) Conducting subsequent performance tests to demonstrate continuous compliance once every five years.
(c) For each venturi scrubber applied to pushing emissions and subject to the operating limits in § 63.7290(f)(1), you must demonstrate continuous compliance by meeting the requirements in paragraphs (c)(1) through (3) of this section.
(1) Maintaining the daily average pressure drop and scrubber water flow rate at levels no lower than those established during the initial or subsequent performance test.
(2) Operating and maintaining each CPMS according to § 63.7331(b) and recording all information needed to document conformance with these requirements.
(3) Collecting and reducing monitoring data for pressure drop and scrubber water flow rate according to § 63.7331(e)(1) through (3).
(d) For each hot water scrubber applied to pushing emissions and subject to the operating limits in § 63.7290(f)(2), you must demonstrate continuous compliance by meeting the requirements in paragraphs (d)(1) through (3) of this section.
(1) Maintaining the daily average water pressure and temperature at levels no lower than those established during the initial or subsequent performance test.
(2) Operating and maintaining each CPMS according to § 63.7331(b) and recording all information needed to document conformance with these requirements.
(3) Collecting and reducing monitoring data for water pressure and temperature according to § 63.7331(f).
(e) For each capture system applied to pushing emissions and subject to the operating limit in § 63.7290(f)(3), you must demonstrate continuous compliance by meeting the requirements in paragraph (e)(1), (2), or (3) of this section:
(1) If you elect the operating limit for volumetric flow rate in § 63.7290(f)(3):
(i) Maintaining the daily average volumetric flow rate at the inlet of the control device at or above the minimum level established during the initial or subsequent performance test; and
(ii) Checking the volumetric flow rate at least every 8 hours to verify the daily average is at or above the minimum level established during the initial or subsequent performance test and recording the results of each check.
(2) If you elect the operating limit for fan motor amperes in § 63.7290(f)(3)(i):
(i) Maintaining the daily average fan motor amperages at or above the minimum level established during the initial or subsequent performance test; and
(ii) Checking the fan motor amperage at least every 8 hours to verify the daily average is at or above the minimum level established during the initial or subsequent performance test and recording the results of each check.
(3) If you elect the operating limit for static pressure or fan RPM in § 63.7290(f)(3)(ii):
(i) Maintaining the daily average static pressure at the inlet to the control device at an equal or greater vacuum than established during the initial or subsequent performance test or the daily average fan RPM at or above the minimum level established during the initial or subsequent performance test; and
(ii) Checking the static pressure or fan RPM at least every 8 hours to verify the daily average static pressure at the inlet to the control device is at an equal or greater vacuum than established during the initial or subsequent performance test or the daily average fan RPM is at or above the minimum level established during the initial or subsequent performance test and recording the results of each check.
(f) Beginning on the first day compliance is required under § 63.7283, you must demonstrate continuous compliance for each by-product coke oven battery subject to the opacity limit for battery stacks in § 63.7296(a) by meeting the requirements in paragraphs (f)(1) and (2) of this section:
(1) Maintaining the daily average opacity at or below 15 percent for a battery on a normal coking cycle or 20 percent for a battery on batterywide extended coking; and
(2) Operating and maintaining a COMS and collecting and reducing the COMS data according to § 63.7331(j).
(g) For each battery stack subject to the emission limits in § 63.7296(c) through (f), you must demonstrate continuous compliance by meeting the requirements in paragraphs (g)(1) through (5) of this section:
(1) Maintaining emissions of particulate matter at or below the applicable limits in § 63.7296(c);
(2) Maintaining emissions of mercury at or below the applicable limits in § 63.7296(d);
(3) Maintaining emissions of total acid gases at or below the applicable limits in § 63.7296(e);
(4) Maintaining emissions of hydrogen cyanide at or below the applicable limits in § 63.7296(f); and
(5) Conducting subsequent performance tests to demonstrate continuous compliance once every five years.
(h) Beginning on the first day compliance is required under § 63.7283, you must demonstrate continuous compliance with the TDS limit for quenching in § 63.7295(a)(1)(i) by meeting the requirements in paragraphs (h)(1) and (2) of this section:
(1) Maintaining the TDS content of the water used to quench hot coke at 1,100 mg/L or less; and
(2) Determining the TDS content of the quench water at least weekly according to the requirements in § 63.7325(a) and recording the sample results.
(i) Beginning on the first day compliance is required under § 63.7283, you must demonstrate continuous compliance with the constituent limit for quenching in § 63.7295(a)(1)(ii) by meeting the requirements in paragraphs (i)(1) and (2) of this section:
(1) Maintaining the sum of the concentrations of benzene, benzo(a)pyrene, and naphthalene in the water used to quench hot coke at levels less than or equal to the site-specific limit approved by the permitting authority; and
(2) Determining the sum of the constituent concentrations at least monthly according to the requirements in § 63.7325(c) and recording the sample results.
(j) For each multicyclone applied to pushing emissions and subject to the operating limit in § 63.7290(f)(4), you must demonstrate compliance by meeting the requirements in paragraphs (j)(1) through (3) of this section.
(1) Maintaining the daily average pressure drop at a level at or below the level established during the initial or subsequent performance test.
(2) Operating and maintaining each CPMS according to § 63.7331(k) and recording all information needed to document conformance with these requirements.
(3) Collecting and reducing monitoring data for pressure drop according to § 63.7331(e)(1) through (3).
(k) For each HNR HRSG main stack subject to the emission limits in § 63.7297(a) through (d), you must demonstrate continuous compliance by meeting the requirements in paragraphs (k)(1) through (5) of this section:
(1) Maintaining emissions of particulate matter at or below the applicable limits in § 63.7297(a);
(2) Maintaining emissions of mercury at or below the applicable limits in § 63.7297(b);
(3) Maintaining emissions of total acid gases at or below the applicable limits in § 63.7297(c);
(4) Maintaining emissions of total PAHs at or below the applicable limits in § 63.7297(d); and
(5) Conducting subsequent performance tests to demonstrate continuous compliance once every five years.
(l) For each HNR HRSG bypass/waste heat stack subject to the emission limits in § 63.7298(a) through (e), you must demonstrate continuous compliance by meeting the requirements in paragraphs (l)(1) through (6) of this section:
(1) Maintaining emissions of particulate matter at or below the applicable limits in § 63.7298(a);
(2) Maintaining emissions of mercury at or below the applicable limits in § 63.7298(b);
(3) Maintaining emissions of total acid gases at or below the applicable limits in § 63.7298(c);
(4) Maintaining emissions of total PAHs at or below the applicable limits in § 63.7298(d);
(5) Maintaining emissions of total formaldehyde at or below the applicable limits in § 63.7298(e); and
(6) Conducting subsequent performance tests to demonstrate continuous compliance once every five years.
§ 63.7334   How do I demonstrate continuous compliance with the work practice standards that apply to me?
(a) For each by-product coke oven battery with vertical flues subject to the work practice standards for fugitive pushing emissions in § 63.7291(a), you must demonstrate continuous compliance according to the requirements of paragraphs (a)(1) through (8) of this section:
(1) Observe and record the opacity of fugitive emissions for four consecutive pushes per operating day, except you may make fewer or non-consecutive observations as permitted by § 63.7291(a)(3). Maintain records of the pushing schedule for each oven and records indicating the legitimate operational reason for any change in the pushing schedule according to § 63.7291(a)(4).
(2) Observe and record the opacity of fugitive emissions from each oven in a battery at least once every 90 days. If an oven cannot be observed during a 90-day period, observe and record the opacity of the first push of that oven following the close of the 90-day period that can be read in accordance with the procedures in paragraphs (a)(1) through (8) of this section.
(3) Make all observations and calculations for opacity observations of fugitive pushing emissions in accordance with Method 9 in appendix A-4 to 40 CFR part 60 using a Method 9 certified observer unless you have an approved alternative procedure under paragraph (a)(7) of this section. Alternatively, ASTM D7520-16, (incorporated by reference, see § 63.14) may be used with the following conditions:
(i) During the digital camera opacity technique (DCOT) certification procedure outlined in section 9.2 of ASTM D7520-16 (incorporated by reference, see § 63.14), the owner or operator or the DCOT vendor must present the plumes in front of various backgrounds of color and contrast representing conditions anticipated during field use such as blue sky, trees, and mixed backgrounds (clouds and/or a sparse tree stand).
(ii) The owner or operator must also have standard operating procedures in place including daily or other frequency quality checks to ensure the equipment is within manufacturing specifications as outlined in section 8.1 of ASTM D7520-16 (incorporated by reference, see § 63.14).
(iii) The owner or operator must follow the recordkeeping procedures outlined in § 63.10(b)(1) for the DCOT certification, compliance report, data sheets, and all raw unaltered JPEGs used for opacity and certification determination.
(iv) The owner or operator or the DCOT vendor must have a minimum of four independent technology users apply the software to determine the visible opacity of the 300 certification plumes. For each set of 25 plumes, the user may not exceed 15 percent opacity of anyone reading and the average error must not exceed 7.5 percent opacity.
(v) Use of this approved alternative does not provide or imply a certification or validation of any vendor's hardware or software. The onus to maintain and verify the certification and/or training of the DCOT camera, software, and operator in accordance with ASTM D7520-16 (incorporated by reference, see § 63.14) and these requirements is on the facility, DCOT operator, and DCOT vendor.
(4) Record pushing opacity observations at 15-second intervals as required in section 2.4 of Method 9 in appendix A-4 to 40 CFR part 60. The requirement in section 2.4 of Method 9 for a minimum of 24 observations does not apply, and the data reduction requirements in section 2.5 of Method 9 do not apply. The requirement in § 63.6(h)(5)(ii)(B) for obtaining at least 3 hours of observations (thirty 6-minute averages) to demonstrate initial compliance does not apply. Alternatively, ASTM D7520-16, (incorporated by reference, see § 63.14) may be used with the following conditions:
(i) During the digital camera opacity technique (DCOT) certification procedure outlined in section 9.2 of ASTM D7520-16 (incorporated by reference, see § 63.14), the owner or operator or the DCOT vendor must present the plumes in front of various backgrounds of color and contrast representing conditions anticipated during field use such as blue sky, trees, and mixed backgrounds (clouds and/or a sparse tree stand).
(ii) The owner or operator must also have standard operating procedures in place including daily or other frequency quality checks to ensure the equipment is within manufacturing specifications as outlined in section 8.1 of ASTM D7520-16 (incorporated by reference, see § 63.14).
(iii) The owner or operator must follow the recordkeeping procedures outlined in § 63.10(b)(1) for the DCOT certification, compliance report, data sheets, and all raw unaltered JPEGs used for opacity and certification determination.
(iv) The owner or operator or the DCOT vendor must have a minimum of four independent technology users apply the software to determine the visible opacity of the 300 certification plumes. For each set of 25 plumes, the user may not exceed 15 percent opacity of anyone reading and the average error must not exceed 7.5 percent opacity.
(v) Use of this approved alternative does not provide or imply a certification or validation of any vendor's hardware or software. The onus to maintain and verify the certification and/or training of the DCOT camera, software, and operator in accordance with ASTM D7520-16 (incorporated by reference, see § 63.14) and these requirements is on the facility, DCOT operator, and DCOT vendor.
(5) If fewer than six but at least four 15-second observations can be made, use the average of the total number of observations to calculate average opacity for the push. Missing one or more observations during the push ( e.g., as the quench car passes behind a building) does not invalidate the observations before or after the interference for that push. However, a minimum of four 15-second readings must be made for a valid observation.
(6) Begin observations for a push at the first detectable movement of the coke mass. End observations of a push when the quench car enters the quench tower.
(i) For a battery without a cokeside shed, observe fugitive pushing emissions from a position at least 10 meters from the quench car that provides an unobstructed view and avoids interferences from the topside of the battery. This may require the observer to be positioned at an angle to the quench car rather than perpendicular to it. Typical interferences to avoid include emissions from open standpipes and charging. Observe the opacity of emissions above the battery top with the sky as the background where possible. Record the oven number of any push not observed because of obstructions or interferences.
(ii) For a battery with a cokeside shed, the observer must be in a position that provides an unobstructed view and avoids interferences from the topside of the battery. Typical interferences to avoid include emissions from open standpipes and charging. Observations must include any fugitive emissions that escape from the top of the shed, from the ends of the shed, or from the area where the shed is joined to the battery. If the observer does not have a clear view to identify when a push starts or ends, a second person can be positioned to signal the start or end of the push and notify the observer when to start or end the observations. Radio communications with other plant personnel ( e.g., pushing ram operator or quench car operator) may also serve to notify the observer of the start or end of a push. Record the oven number of any push not observed because of obstructions or interferences.
(iii) You may reposition after the push to observe emissions during travel if necessary.
(7) If it is infeasible to implement the procedures in paragraphs (a)(1) through (6) of this section for an oven due to physical obstructions, nighttime pushes, or other reasons, you may apply to your permitting authority for permission to use an alternative procedure. The application must provide a detailed explanation of why it is infeasible to use the procedures in paragraphs (a)(1) through (6) of this section, identify the oven and battery numbers, and describe the alternative procedure. An alternative procedure must identify whether the coke in that oven is not completely coked, either before, during, or after an oven is pushed.
(8) For each oven observed that exceeds an opacity of 30 percent for any short battery or 35 percent for any tall battery, you must take corrective action and/or increase the coking time in accordance with § 63.7291(a). Maintain records documenting conformance with the requirements in § 63.7291(a).
(b) For each by-product coke oven battery with horizontal flues subject to the work practice standards for fugitive pushing emissions in § 63.7292(a), you must demonstrate continuous compliance by having met the requirements of paragraphs (b)(1) through (3) of this section:
(1) Measuring and recording the temperature of all flues on two ovens per day within 2 hours before the oven's scheduled pushing time and ensuring that the temperature of each oven is measured and recorded at least once every month;
(2) Recording the time each oven is charged and pushed and calculating and recording the net coking time for each oven; and
(3) Increasing the coking time for each oven that falls below the minimum flue temperature trigger established for that oven's coking time in the written plan required in § 63.7292(a)(1), assigning the oven to the oven-directed program, and recording all relevant information according to the requirements in § 63.7292(a)(4) including, but not limited to, daily pushing schedules, diagnostic procedures, corrective actions, and oven repairs.
(c) For each nonrecovery coke oven battery subject to the work practice standards in § 63.7293(a), you must demonstrate continuous compliance by maintaining records that document each visual inspection of an oven prior to pushing and that the oven was not pushed unless there was no smoke in the open space above the coke bed and there was an unobstructed view of the door on the opposite side of the oven.
(d) For each by-product coke oven battery subject to the work practice standard for soaking in § 63.7294(a), you must demonstrate continuous compliance by maintaining records that document conformance with requirements in § 63.7294(a)(1) through (5).
(e) For each coke oven battery subject to the work practice standard for quenching in § 63.7295(b), you must demonstrate continuous compliance according to the requirements of paragraphs (e)(1) through (3) of this section:
(1) Maintaining baffles in each quench tower such that no more than 5 percent of the cross-sectional area of the tower is uncovered or open to the sky as required in § 63.7295(b)(1);
(2) Maintaining records that document conformance with the washing, inspection, and repair requirements in § 63.7295(b)(2), including records of the ambient temperature on any day that the baffles were not washed; and
(3) Maintaining records of the source of makeup water to document conformance with the requirement for acceptable makeup water in § 63.7295(a)(2).
§ 63.7335   How do I demonstrate continuous compliance with the operation and maintenance requirements that apply to me?
(a) For each by-product coke oven battery, you must demonstrate continuous compliance with the operation and maintenance requirements in § 63.7300(b) by adhering at all times to the plan requirements and recording all information needed to document conformance.
(b) For each coke oven battery with a capture system or control device applied to pushing emissions, you must demonstrate continuous compliance with the operation and maintenance requirements in § 63.7300(c) by meeting the requirements of paragraphs (b)(1) through (3) of this section:
(1) Making monthly inspections of capture systems according to § 63.7300(c)(1) and recording all information needed to document conformance with these requirements;
(2) Performing preventative maintenance for each control device according to § 63.7300(c)(2) and recording all information needed to document conformance with these requirements; and
(3) Initiating and completing corrective action for a bag leak detection system alarm according to § 63.7300(c)(3) and recording all information needed to document conformance with these requirements. This includes records of the times the bag leak detection system alarm sounds, and for each valid alarm, the time you initiated corrective action, the corrective action(s) taken, and the date on which corrective action is completed.
(c) To demonstrate continuous compliance with the operation and maintenance requirements for a baghouse applied to pushing emissions from a coke oven battery in § 63.7331(a), you must inspect and maintain each baghouse according to the requirements in § 63.7331(a)(1) through (8) and record all information needed to document conformance with these requirements. If you increase or decrease the sensitivity of the bag leak detection system beyond the limits specified in § 63.7331(a)(6), you must include a copy of the required written certification by a responsible official in the next semiannual compliance report.
(d) You must maintain a current copy of the operation and maintenance plans required in § 63.7300(b) and (c) onsite and available for inspection upon request. You must keep the plans for the life of the affected source or until the affected source is no longer subject to the requirements of this subpart.
§ 63.7336   What other requirements must I meet to demonstrate continuous compliance?
You must report each instance in which you did not meet each emission limitation in this subpart that applies to you. This includes periods of startup, shutdown, and malfunction. You must also report each instance in which you did not meet each work practice standard or operation and maintenance requirement in this subpart that applies to you. These instances are deviations from the emission limitations (including operating limits), work practice standards, and operation and maintenance requirements in this subpart. These deviations must be reported according to the requirements in § 63.7341.
(a) In the event that an affected unit fails to meet an applicable standard, record the number of failures. For each failure, record the start date, start time and duration (in hours) of each failure.
(b) For each failure to meet an applicable standard, record and retain a list of the affected sources or equipment, an estimate of the quantity of each regulated pollutant emitted over any emission limit and a description of the method used to estimate the emissions.
(c) Record actions taken to minimize emissions in accordance with § 63.7310(a), and any corrective actions taken to return the affected unit to its normal or usual manner of operation.
§ 63.7340   What notifications must I submit and when?
(a) You must submit all of the notifications in §§ 63.6(h)(4) and (5), 63.7(b) and (c), 63.8(e) and (f)(4), and 63.9(b) through (h) that apply to you by the specified dates.
(b) As specified in § 63.9(b)(2), if you startup your affected source before April 14, 2003, you must submit your initial notification no later than August 12, 2003, or no later than 120 days after the source becomes subject to this subpart, whichever is later.
(c) As specified in § 63.9(b)(3), if you startup your new affected source on or after April 14, 2003, you must submit your initial notification no later than 120 calendar days after you become subject to this subpart.
(d) If you are required to conduct a performance test, you must submit a notification of intent to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin as required in § 63.7(b)(1).
(e) If you are required to conduct a performance test, opacity observation, or other initial compliance demonstration, you must submit a notification of compliance status according to § 63.9(h)(2)(ii).
(1) For each initial compliance demonstration that does not include a performance test, you must submit the notification of compliance status before the close of business on the 30th calendar day following the completion of the initial compliance demonstration.
(2) For each initial compliance demonstration that does include a performance test, you must submit the notification of compliance status, including a summary of the performance test results, before the close of business on the 60th calendar day following completion of the performance test according to § 63.10(d)(2).
(f) For each by-product coke oven battery with horizontal flues, you must notify the Administrator (or delegated authority) of the date on which the study of flue temperatures required by § 63.7292(a)(3) will be initiated. You must submit this notification no later than 7 days prior to the date you initiate the study.
§ 63.7341   What reports must I submit and when?
(a) Compliance report due dates. Unless the Administrator has approved a different schedule, you must submit quarterly compliance reports for battery stacks and semiannual compliance reports for all other affected sources to your permitting authority according to the requirements in paragraphs (a)(1) through (4) of this section.
(1) The first quarterly compliance report for battery stacks must cover the period beginning on the compliance date that is specified for your affected source in § 63.7283 and ending on the last date of the third calendar month. Each subsequent compliance report must cover the next calendar quarter.
(2) The first semiannual compliance report must cover the period beginning on the compliance date that is specified for your affected source in § 63.7283 and ending on June 30 or December 31, whichever date comes first after the compliance date that is specified for your affected source. Each subsequent compliance report must cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31.
(3) All quarterly compliance reports for battery stacks must be postmarked or delivered no later than one calendar month following the end of the quarterly reporting period. All semiannual compliance reports must be postmarked or delivered no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period.
(4) For each affected source that is subject to permitting regulations pursuant to 40 CFR part 70 or 40 CFR part 71, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), you may submit the first and subsequent compliance reports according to the dates the permitting authority has established instead of according to the dates in paragraphs (a)(1) through (4) of this section.
(b) Quarterly compliance report contents. Each quarterly report must provide information on compliance with the emission limitations for battery stacks in § 63.7296. The reports must include the information in paragraphs (c)(1) through (3), and as applicable, paragraphs (c)(4) through (8) of this section.
(c) Semiannual compliance report contents. Each compliance report must provide information on compliance with the emission limitations, work practice standards, and operation and maintenance requirements for all affected sources except battery stacks. The reports must include the information in paragraphs (c)(1) through (3) of this section, and as applicable, paragraphs (c)(4) through (8) of this section.
(1) Company name and address (including county).
(2) Statement by a responsible official, with the official's name, title, and signature, certifying the truth, accuracy, and completeness of the content of the report. If your report is submitted via the Compliance and Emissions Data Reporting Interface (CEDRI), the certifier's electronic signature during the submission process replaces this requirement.
(3) Date of report and beginning and ending dates of the reporting period. You are no longer required to provide the date of report when the report is submitted via CEDRI.
(4) Beginning on January 2, 2025, if you failed to meet an applicable standard, the compliance report must include, for each instance, the start date, start time, and duration (in hours) of each failure. For each failure, the compliance report must include a list of the affected sources or equipment, an estimate of the quantity of each regulated pollutant emitted over any emission limit, and a description of the method used to estimate the emissions.
(5) If there were no deviations from the continuous compliance requirements in § 63.7333(e) for battery stacks, a statement that there were no deviations from the emission limitations during the reporting period. If there were no deviations from the continuous compliance requirements in §§ 63.7333 through 63.7335 that apply to you (for all affected sources other than battery stacks), a statement that there were no deviations from the emission limitations, work practice standards, or operation and maintenance requirements during the reporting period.
(6) If there were no periods during which a continuous monitoring system (including COMS, continuous emission monitoring system (CEMS), or CPMS) was out-of-control as specified in § 63.8(c)(7), a statement that there were no periods during which a continuous monitoring system was out-of-control during the reporting period.
(7) For each deviation from an emission limitation in this subpart (including quench water limits) and for each deviation from the requirements for work practice standards in this subpart that occurs at an affected source where you are not using a continuous monitoring system (including a COMS, CEMS, or CPMS) to comply with the emission limitations in this subpart, the compliance report must contain the information in paragraphs (7)(i) and (ii) of this section. This includes periods of startup, shutdown, and malfunction.
(i) The total operating time of each affected source during the reporting period.
(ii) Information on the duration and cause of deviations (including unknown cause, if applicable) as applicable and the corrective action taken.
(8) For each deviation from an emission limitation occurring at an affected source where you are using a continuous monitoring system (including COMS, CEMS, or CPMS) to comply with the emission limitation in this subpart, you must include the information in paragraphs (c)(4) and (8)(i) through (xii) of this section. This includes periods of startup, shutdown, and malfunction.
(i) The date and time that each malfunction started and stopped.
(ii) The start date, start time, and duration in hours that each continuous monitoring system (including COMS, CEMS, or CPMS) was inoperative, except for zero (low-level) and high-level checks.
(iii) The start date, start time, and duration in hours that each continuous monitoring system (including COMS, CEMS, or CPMS) was out-of-control, including the information in § 63.8(c)(8).
(iv) The date and time that each deviation started and stopped, the duration in hours, and whether each deviation occurred during a period of startup, shutdown, or malfunction or during another period.
(v) A summary of the total duration in hours of the deviation during the reporting period and the total duration as a percent of the total source operating time during that reporting period.
(vi) A breakdown of the total duration in hours of the deviations during the reporting period into those that are due to startup, shutdown, control equipment problems, process problems, other known causes, and other unknown causes.
(vii) A summary of the total duration in hours of continuous monitoring system downtime during the reporting period and the total duration of continuous monitoring system downtime as a percent of the total source operating time during the reporting period.
(viii) An identification of each HAP that was monitored at the affected source.
(ix) A brief description of the process units.
(x) A brief description of the continuous monitoring system.
(xi) The date of the latest continuous monitoring system certification or audit.
(xii) A description of any changes in continuous monitoring systems, processes, or controls since the last reporting period.
(xiii) The total operating time of each affected source during the reporting period.
(d) [Reserved]
(e) Part 70 monitoring report. If you have obtained a title V operating permit for an affected source pursuant to 40 CFR part 70 or 40 CFR part 71, you must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If you submit a compliance report for an affected source along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the compliance report includes all the required information concerning deviations from any emission limitation or work practice standard in this subpart, submission of the compliance report satisfies any obligation to report the same deviations in the semiannual monitoring report. However, submission of a compliance report does not otherwise affect any obligation you may have to report deviations from permit requirements to your permitting authority.
(f) Electronic reporting of compliance reports. Beginning on July 7, 2026, or once the report template for this subpart has been available on the CEDRI website for one year, whichever date is later, submit all subsequent reports to the EPA via the CEDRI according to § 63.9(k) except that confidential business information (CBI) should be submitted according to paragraph (h) of this section.
(g) Electronic Reporting of Performance Tests. Beginning on September 3, 2024, within 60 days after the date of completing each performance test required by this subpart, you must submit the results of the performance test following the procedure specified in § 63.9(k). CBI should be submitted according to paragraph (h) of this section. Data collected using test methods supported by the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT website ( https://www.epa.gov/electronic-reporting-air-emissions/electronic-reporting-tool-ert ) at the time of the test must be submitted in a file format generated using the EPA's ERT. Alternatively, you may submit an electronic file consistent with the extensible markup language (XML) schema listed on the EPA's ERT website. Data collected using test methods that are not supported by the EPA's ERT as listed on the EPA's ERT website at the time of the test must be included as an attachment in the ERT or alternate electronic file. If a performance test consists only of opacity measurements, reporting using the ERT and CEDRI is not required.
(h) Confidential business information (CBI). For notifications and reports required to be submitted to CEDRI:
(1) The EPA will make all the information submitted through CEDRI available to the public without further notice to you. Do not use CEDRI to submit information you claim as CBI. Although we do not expect persons to assert a claim of CBI, if you wish to assert a CBI claim for some of the information submitted under paragraph (f) or (g) of this section, you must submit a complete file, including information claimed to be CBI, to the EPA.
(2) For performance test reports according to paragraph (g) of this section, the file must be generated using the EPA's ERT or an alternate electronic file consistent with the XML schema listed on the EPA's ERT website.
(3) Clearly mark the part or all of the information that you claim to be CBI. Information not marked as CBI may be authorized for public release without prior notice. Information marked as CBI will not be disclosed except in accordance with procedures set forth in 40 CFR part 2.
(4) The preferred method to receive CBI is for it to be transmitted electronically using email attachments, File Transfer Protocol, or other online file sharing services. Electronic submissions must be transmitted directly to the OAQPS CBI Office at the email address oaqpscbi@epa.gov, and as described above, should include clear CBI markings. For performance test reports, CBI should be flagged to the attention of, the Group Leader, Measurement Policy Group; for all other reports and notifications, the Coke Ovens Sector Lead should be flagged. If assistance is needed with submitting large electronic files that exceed the file size limit for email attachments, and if you do not have your own file sharing service, please email oaqpscbi@epa.gov to request a file transfer link.
(5) If you cannot transmit the file electronically, you may send CBI information through the postal service to the following address: OAQPS Document Control Officer (C404-02), OAQPS, U.S. Environmental Protection Agency, Research Triangle Park, North Carolina 27711, Attention Group Leader, Measurement Policy Group or Coke Oven Sector Lead as indicated in paragraph (4) of this section. The mailed CBI material should be double wrapped and clearly marked. Any CBI markings should not show through the outer envelope.
(6) All CBI claims must be asserted at the time of submission. Anything submitted using CEDRI cannot later be claimed CBI. Furthermore, under CAA section 114(c), emissions data is not entitled to confidential treatment, and the EPA is required to make emissions data available to the public. Thus, emissions data will not be protected as CBI and will be made publicly available.
(7) You must submit the same file submitted to the CBI office with the CBI omitted to the EPA via the EPA's CDX as described in paragraph (f) or (g) of this section.
§ 63.7342   What records must I keep?
(a) You must keep the records specified in paragraphs (a)(1) through (5) of this section.
(1) A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any initial notification or notification of compliance status that you submitted, according to the requirements in § 63.10(b)(2)(xiv).
(2) Beginning on January 2, 2025, records of the occurrence and duration of each startup, shutdown, or malfunction of process, air pollution control, and monitoring equipment.
(3) Beginning on January 2, 2025, for each failure to meet an applicable standard, a list of the affected sources or equipment, whether the failure occurred during startup, shutdown, or malfunction, and records of the start date, start time, and duration (in hours) of each failure to meet an applicable standard. Include an estimate of the quantity of each regulated pollutant emitted over any emission limit, and a description of the method used to estimate the emissions.
(4) Beginning on January 2, 2025, records of the actions taken to minimize emissions in accordance with § 63.7310(a), and any corrective actions taken to return the affected unit to its normal or usual manner of operation.
(5) Records of performance tests, performance evaluations, and opacity observations as required in § 63.10(b)(2)(viii).
(b) For each COMS or CEMS, you must keep the records specified in paragraphs (b)(1) through (4) of this section.
(1) Records described in § 63.10(b)(2)(vi) through (xi).
(2) Monitoring data for COMS during a performance evaluation as required in § 63.6(h)(7)(i) and (ii).
(3) You shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the Administrator. If the performance evaluation plan is revised, you shall keep previous ( i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. The program of corrective action should be included in the plan required under § 63.8(d)(2).
(4) Records of the date and time that each deviation started and stopped, the cause of the deviation, and whether the deviation occurred during a period of startup, shutdown, or malfunction or during another period.
(c) You must keep the records in § 63.6(h)(6) for visual observations.
(d) You must keep the records required in §§ 63.7333 through 63.7335 to show continuous compliance with each emission limitation, work practice standard, and operation and maintenance requirement that applies to you.
§ 63.7343   In what form and how long must I keep my records?
(a) You must keep your records in a form suitable and readily available for expeditious review, according to § 63.10(b)(1).
(b) As specified in § 63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record.
(c) You must keep each record on site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to § 63.10(b)(1). You can keep the records offsite for the remaining 3 years.
§ 63.7350   What parts of the General Provisions apply to me?
Table 1 to this subpart shows which parts of the General Provisions in §§ 63.1 through 63.15 apply to you.
§ 63.7351   Who implements and enforces this subpart?
(a) This subpart can be implemented and enforced by us, the United States Environmental Protection Agency (U.S. EPA), or a delegated authority such as your State, local, or tribal agency. If the U.S. EPA Administrator has delegated authority to your State, local, or tribal agency, then that agency has the authority to implement and enforce this subpart. You should contact your U.S. EPA Regional Office to find out if this subpart is delegated to your State, local, or tribal agency.
(b) In delegating implementation and enforcement authority of this subpart to a State, local, or tribal agency under subpart E of this part, the authorities contained in paragraph (c) of this section are retained by the Administrator of the U.S. EPA and are not transferred to the State, local, or tribal agency.
(c) The authorities in paragraphs (c)(1) through (6) of this section will not be delegated to State, local, or tribal agencies.
(1) Approval of alternatives to work practice standards for fugitive pushing emissions in § 63.7291(a) for a by-product coke oven battery with vertical flues, fugitive pushing emissions in § 63.7292(a) for a by-product coke oven battery with horizontal flues, fugitive pushing emissions in § 63.7293 for a nonrecovery coke oven battery, soaking for a by-product coke oven battery in § 63.7294(a), and quenching for a coke oven battery in § 63.7295(b) under § 63.6(g).
(2) Approval of alternative opacity emission limitations for a by-product coke oven battery under § 63.6(h)(9).
(3) Approval of major alternatives to test methods under § 63.7(e)(2)(ii) and (f) and as defined in § 63.90, except for alternative procedures in § 63.7334(a)(7).
(4) Approval of major alternatives to monitoring under § 63.8(f) and as defined in § 63.90.
(5) Approval of major alternatives to recordkeeping and reporting under § 63.10(f) and as defined in § 63.90.
(6) Approval of the work practice plan for by-product coke oven batteries with horizontal flues submitted under § 63.7292(a)(1).
(7) Approval of an alternative to any electronic reporting to the EPA required by this subpart.
§ 63.7352   What definitions apply to this subpart?
Terms used in this subpart are defined in the Clean Air Act (CAA), in § 63.2, and in this section as follows:
Acceptable makeup water means surface water from a river, lake, or stream; water meeting drinking water standards; storm water runoff and production area clean up water except for water from the by-product recovery plant area; process wastewater treated to meet effluent limitations guidelines in 40 CFR part 420; water from any of these sources that has been used only for non-contact cooling or in water seals; or water from scrubbers used to control pushing emissions.
Backup quench station means a quenching device that is used for less than 5 percent of the quenches from any single coke oven battery in the 12-month period from July 1 to June 30.
Baffles means an apparatus comprised of obstructions for checking or deflecting the flow of gases. Baffles are installed in a quench tower to remove droplets of water and particles from the rising vapors by providing a point of impact. Baffles may be installed either inside or on top of quench towers and are typically constructed of treated wood, steel, or plastic.
Battery stack means the stack that is the point of discharge to the atmosphere of the combustion gases from a battery's underfiring system.
Battery waste heat flues means the channels outside the coke oven and between the wall separating adjacent ovens as well as each end wall. At any one time, half of the flues in a given wall will be burning gas while the other half will be conveying waste heat from the combustion flues to a brick heat exchanger and then on to the battery combustion stack.
Batterywide extended coking means increasing the average coking time for all ovens in the coke oven battery by 25 percent or more over the manufacturer's specified design rate.
Bypass stack at a heat recovery facility means a stack through which emissions are discharged from a common tunnel that collects gases from a coke oven battery. and where the emissions are not passed through a heat recovery unit. Common tunnels typically are equipped with afterburners to further reduce organic emissions in the coke oven gas.
By-product coke oven battery means a group of ovens connected by common walls, where coal undergoes destructive distillation under positive pressure to produce coke and coke oven gas from which by-products are recovered.
By-product recovery plant area means that area of the coke plant where process units subject to subpart L in part 61 are located.
Coke oven battery means a group of ovens connected by common walls, where coal undergoes destructive distillation to produce coke. A coke oven battery includes by-product and nonrecovery processes.
Coke plant means a facility that produces coke from coal in either a by-product coke oven battery or a nonrecovery coke oven battery.
Cokeside shed means a structure used to capture pushing emissions that encloses the cokeside of the battery and ventilates the emissions to a control device.
Coking time means the time interval that starts when an oven is charged with coal and ends when the oven is pushed.
Deviation means any instance in which an affected source subject to this subpart, or an owner or operator of such a source:
(1) Fails to meet any requirement or obligation established by this subpart including, but not limited to, any emission limitation (including operating limits) or work practice standard;
(2) Fails to meet any term or condition that is adopted to implement an applicable requirement in this subpart and that is included in the operating permit for any affected source required to obtain such a permit; or
(3) Fails to meet any emission limitation or work practice standard in this subpart during startup, shutdown, or malfunction, regardless of whether or not such failure is permitted by this subpart.
Emission limitation means any emission limit, opacity limit, or operating limit.
Four consecutive pushes means four pushes observed successively.
Fugitive pushing emissions means emissions from pushing that are not collected by a capture system.
Heat and/or nonrecovery coke oven battery means a group of ovens, connected by common side walls, in which coal undergoes destructive distillation under negative pressure to produce coke and coke oven gas and from which by-products are not recovered. The common tunnels typically contain afterburners to further reduce organic emissions in the coke oven gas. For nonrecovery plants ( i.e., no chemical recovery) with heat recovery, the oven gases are vented through common tunnels to a heat recovery steam generator that produces steam. Heat recovery coke oven batteries may release oven gases through common tunnels and then into the atmosphere through bypass stacks when the heat recovery steam generators are not available due to maintenance or repair. For nonrecovery coke oven batteries ( i.e., no chemical recovery) without heat recovery, oven gases are vented through common tunnels and then released to the atmosphere through waste heat stacks.
Heat recovery steam generator is a process unit that recovers heat from coke oven gas in order to produce steam. Units typically are equipped with desulfurization units and baghouses to remove pollutants from the exhaust gases.
Heat recovery steam generator bypass/waste heat stack means a stack that allows coke oven gas to be vented from the coke oven batteries through common tunnels and into the atmosphere when there are no heat recovery steam generator units available for heat recovery. Common tunnels typically are equipped with afterburners to further reduce organic emissions in the coke oven gas.
Heat recovery steam generator main stack means the stack that is the point of final discharge to the atmosphere of the gases emanating from a heat recovery steam generator and its control devices, which typically are desulfurization units and baghouses.
Horizontal flue means a type of coke oven heating system used on Semet-Solvay batteries where the heating flues run horizontally from one end of the oven to the other end, and the flues are not shared with adjacent ovens.
Hot water scrubber means a mobile scrubber used to control pushing emissions through the creation of an induced draft formed by the expansion of pressurized hot water through a nozzle.
Increased coking time means increasing the charge-to-push time for an individual oven.
Nonrecovery coke oven battery means a group of ovens, connected by common walls, where coal undergoes destructive distillation under negative pressure to produce coke and which is designed for the combustion of the coke oven gas from which by-products are not recovered. Also known as a heat and/or nonrecovery battery. Nonrecovery coke oven battery refers to units from which heat is recovered from the coke oven gas exhaust as well as units where heat is not recovered. Both heat and/or nonrecovery batteries are connected by common tunnels that typically include afterburners to further reduce organic emissions in the coke oven gas.
Oven means a chamber in the coke oven battery in which coal undergoes destructive distillation to produce coke.
Pushing means the process of removing the coke from the oven. Pushing begins with the first detectable movement of the coke mass and ends when the quench car enters the quench tower.
Pushing/charging machine (PCM) means the combined coke oven pushing and charging machine operated on rail tracks to open an oven door, push the finished coke from the open oven, and close the oven door, and to charge the adjacent oven with coal to start the coking cycle. Typically used with horizontal ovens such as those at nonrecovery coke facilities.
Quenching means the wet process of cooling (wet quenching) the hot incandescent coke by direct contact with water that begins when the quench car enters the quench tower and ends when the quench car exits the quench tower.
Quench tower means the structure in which hot incandescent coke in the quench car is deluged or quenched with water.
Remove from service means that an oven is not charged with coal and is not used for coking. When removed from service, the oven may remain at the operating temperature or it may be cooled down for repairs.
Responsible official means responsible official as defined in § 63.2.
Short battery means a by-product coke oven battery with ovens less than five meters in height.
Soaking means that period in the coking cycle that starts when an oven is dampered off the collecting main and vented to the atmosphere through an open standpipe prior to pushing and ends when the coke begins to be pushed from the oven.
Soaking emissions means the discharge from an open standpipe during soaking of visible emissions due to either incomplete coking or leakage into the standpipe from the collecting main.
Standpipe means an apparatus on the oven that provides a passage for gases from an oven to the atmosphere when the oven is dampered off the collecting main and the standpipe cap is opened. This includes mini-standpipes that are not connected to the collecting main.
Tall battery means a by-product coke oven battery with ovens five meters or more in height.
Total acid gases means the sum of hydrogen chloride and hydrogen fluoride.
Total polycyclic aromatic hydrocarbons (total PAH) means the sum of acenaphthene, acenaphthylene, anthracene, benz[a]anthracene, benzo[a]pyrene, benzo[b]fluoranthene, benzo[g,h,i]perylene, benzo[k]fluoranthene, chrysene, dibenz[a,h]anthracene, fluoranthene, fluorene, indeno (1,2,3-cd) pyrene, naphthalene, phenanthrene, perylene, and pyrene.
Vertical flue means a type of coke oven heating system in which the heating flues run vertically from the bottom to the top of the oven, and flues are shared between adjacent ovens.
Waste heat stack at a heat and/or nonrecovery facility means a stack that allows coke oven gas to be vented from the coke oven batteries through common tunnels and into the atmosphere when there are no units available for heat recovery. Common tunnels typically contain afterburners to further reduce organic emissions in coke oven gas.
Work practice standard means any design, equipment, work practice, or operational standard, or combination thereof, that is promulgated pursuant to section 112(h) of the CAA.
§ 63.7480   What is the purpose of this subpart?
This subpart establishes national emission limitations and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards.
§ 63.7485   Am I subject to this subpart?
You are subject to this subpart if you own or operate an industrial, commercial, or institutional boiler or process heater as defined in § 63.7575 that is located at, or is part of, a major source of HAP, except as specified in § 63.7491. For purposes of this subpart, a major source of HAP is as defined in § 63.2, except that for oil and natural gas production facilities, a major source of HAP is as defined in § 63.7575.
§ 63.7490   What is the affected source of this subpart?
(a) This subpart applies to new, reconstructed, and existing affected sources as described in paragraphs (a)(1) and (2) of this section.
(1) The affected source of this subpart is the collection at a major source of all existing industrial, commercial, and institutional boilers and process heaters within a subcategory as defined in § 63.7575.
(2) The affected source of this subpart is each new or reconstructed industrial, commercial, or institutional boiler or process heater, as defined in § 63.7575, located at a major source.
(b) A boiler or process heater is new if you commence construction of the boiler or process heater after June 4, 2010, and you meet the applicability criteria at the time you commence construction.
(c) A boiler or process heater is reconstructed if you meet the reconstruction criteria as defined in § 63.2, you commence reconstruction after June 4, 2010, and you meet the applicability criteria at the time you commence reconstruction.
(d) A boiler or process heater is existing if it is not new or reconstructed.
(e) An existing electric utility steam generating unit (EGU) that meets the applicability requirements of this subpart after the effective date of this final rule due to a change (e.g., fuel switch) is considered to be an existing source under this subpart.
§ 63.7491   Are any boilers or process heaters not subject to this subpart?
The types of boilers and process heaters listed in paragraphs (a) through (n) of this section are not subject to this subpart.
(a) An electric utility steam generating unit (EGU) covered by subpart UUUUU of this part or a natural gas-fired EGU as defined in subpart UUUUU of this part firing at least 85 percent natural gas on an annual heat input basis.
(b) A recovery boiler or furnace covered by subpart MM of this part.
(c) A boiler or process heater that is used specifically for research and development, including test steam boilers used to provide steam for testing the propulsion systems on military vessels. This does not include units that provide heat or steam to a process at a research and development facility.
(d) A hot water heater as defined in this subpart.
(e) A refining kettle covered by subpart X of this part.
(f) An ethylene cracking furnace covered by subpart YY of this part.
(g) Blast furnace stoves as described in EPA-453/R-01-005 (incorporated by reference, see § 63.14).
(h) Any boiler or process heater that is part of the affected source subject to another subpart of this part, such as boilers and process heaters used as control devices to comply with subparts JJJ, OOO, PPP, and U of this part.
(i) Any boiler or process heater that is used as a control device to comply with another subpart of this part, or part 60, part 61, or part 65 of this chapter provided that at least 50 percent of the average annual heat input during any 3 consecutive calendar years to the boiler or process heater is provided by regulated gas streams that are subject to another standard.
(j) Temporary boilers and process heaters as defined in this subpart.
(k) Blast furnace gas fuel-fired boilers and process heaters as defined in this subpart.
(l) Any boiler or process heater specifically listed as an affected source in any standard(s) established under section 129 of the Clean Air Act.
(m) A unit that burns hazardous waste covered by Subpart EEE of this part. A unit that is exempt from Subpart EEE as specified in § 63.1200(b) is not covered by Subpart EEE.
(n) Residential boilers as defined in this subpart.
§ 63.7495   When do I have to comply with this subpart?
(a) If you have a new or reconstructed boiler or process heater, you must comply with this subpart by April 1, 2013, or upon startup of your boiler or process heater, whichever is later.
(b) If you have an existing boiler or process heater, you must comply with this subpart no later than January 31, 2016, except as provided in § 63.6(i).
(c) If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of HAP, paragraphs (c)(1) and (2) of this section apply to you.
(1) Any new or reconstructed boiler or process heater at the existing source must be in compliance with this subpart upon startup.
(2) Any existing boiler or process heater at the existing source must be in compliance with this subpart within 3 years after the source becomes a major source.
(d) You must meet the notification requirements in § 63.7545 according to the schedule in § 63.7545 and in subpart A of this part. Some of the notifications must be submitted before you are required to comply with the emission limits and work practice standards in this subpart.
(e) If you own or operate an industrial, commercial, or institutional boiler or process heater and would be subject to this subpart except for the exemption in § 63.7491(l) for commercial and industrial solid waste incineration units covered by part 60, subpart CCCC or subpart DDDD, and you cease combusting solid waste, you must be in compliance with this subpart and are no longer subject to part 60, subparts CCCC or DDDD beginning on the effective date of the switch as identified under the provisions of § 60.2145(a)(2) and (3) or § 60.2710(a)(2) and (3).
(f) If you own or operate an existing EGU that becomes subject to this subpart after January 31, 2016, you must be in compliance with the applicable existing source provisions of this subpart on the effective date such unit becomes subject to this subpart.
(g) If you own or operate an existing industrial, commercial, or institutional boiler or process heater and would be subject to this subpart except for a exemption in § 63.7491(i) that becomes subject to this subpart after January 31, 2013, you must be in compliance with the applicable existing source provisions of this subpart within 3 years after such unit becomes subject to this subpart.
(h) If you own or operate an existing industrial, commercial, or institutional boiler or process heater and have switched fuels or made a physical change to the boiler or process heater that resulted in the applicability of a different subcategory after the compliance date of this subpart, you must be in compliance with the applicable existing source provisions of this subpart on the effective date of the fuel switch or physical change.
(i) If you own or operate a new industrial, commercial, or institutional boiler or process heater and have switched fuels or made a physical change to the boiler or process heater that resulted in the applicability of a different subcategory, you must be in compliance with the applicable new source provisions of this subpart on the effective date of the fuel switch or physical change.
§ 63.7499   What are the subcategories of boilers and process heaters?
The subcategories of boilers and process heaters, as defined in § 63.7575 are:
(a) Pulverized coal/solid fossil fuel units.
(b) Stokers designed to burn coal/solid fossil fuel.
(c) Fluidized bed units designed to burn coal/solid fossil fuel.
(d) Stokers/sloped grate/other units designed to burn kiln dried biomass/bio-based solid.
(e) Fluidized bed units designed to burn biomass/bio-based solid.
(f) Suspension burners designed to burn biomass/bio-based solid.
(g) Fuel cells designed to burn biomass/bio-based solid.
(h) Hybrid suspension/grate burners designed to burn wet biomass/bio-based solid.
(i) Stokers/sloped grate/other units designed to burn wet biomass/bio-based solid.
(j) Dutch ovens/pile burners designed to burn biomass/bio-based solid.
(k) Units designed to burn liquid fuel that are non-continental units.
(l) Units designed to burn gas 1 fuels.
(m) Units designed to burn gas 2 (other) gases.
(n) Metal process furnaces.
(o) Limited-use boilers and process heaters.
(p) Units designed to burn solid fuel.
(q) Units designed to burn liquid fuel.
(r) Units designed to burn coal/solid fossil fuel.
(s) Fluidized bed units with an integrated fluidized bed heat exchanger designed to burn coal/solid fossil fuel.
(t) Units designed to burn heavy liquid fuel.
(u) Units designed to burn light liquid fuel.
§ 63.7500   What emission limitations, work practice standards, and operating limits must I meet?
(a) You must meet the requirements in paragraphs (a)(1) through (3) of this section, except as provided in paragraphs (b) through (e) of this section. You must meet these requirements at all times the affected unit is operating, except as provided in paragraph (f) of this section.
(1) You must meet each emission limit and work practice standard in Tables 1 through 3 and 11 through 15 to this subpart that applies to your boiler or process heater, for each boiler or process heater at your source, except as provided under § 63.7522. The output-based emission limits, in units of pounds per million Btu of steam output, in Table 1 or 2 to this subpart are an alternative applicable only to boilers and process heaters that generate either steam, cogenerate steam with electricity, or both. The output-based emission limits, in units of pounds per megawatt-hour, in Table 1 or 2 to this subpart are an alternative applicable only to boilers that generate only electricity. Boilers that perform multiple functions (cogeneration and electricity generation) or supply steam to common headers would calculate a total steam energy output using Equation 1 of § 63.7575 to demonstrate compliance with the output-based emission limits, in units of pounds per million Btu of steam output, in Table 1 or 2 to this subpart. If you operate a new boiler or process heater, you can choose to comply with alternative limits as discussed in paragraphs (a)(1)(i) through (iv) of this section, but on or after October 6, 2025, you must comply with the emission limits in Table 1 to this subpart. If you operate an existing boiler or process heater, you can choose to comply with alternative limits as discussed in paragraph (a)(1)(v) of this section, but on or after October 6, 2025 you must comply with the emission limits in Table 2 to this subpart.
(i) If your boiler or process heater commenced construction or reconstruction after June 4, 2010, and before May 20, 2011, you may comply with the emission limits in Table 11 or 14 to this subpart until January 31, 2016.
(ii) If your boiler or process heater commenced construction or reconstruction on or after May 20, 2011, and before December 23, 2011, you may comply with the emission limits in Table 12 or 14 to this subpart until January 31, 2016.
(iii) If your boiler or process heater commenced construction or reconstruction on or after December 23, 2011, and before April 1, 2013, you may comply with the emission limits in Table 13 or 14 to this subpart until January 31, 2016.
(iv) If you operate a new boiler or process heater, you must comply with either the emission limits in Table 1 to this subpart or the emission limits in Table 14 to this subpart until you must comply with the emission limits in Table 1.
(v) If you operate an existing boiler or process heater, you must comply with either the emission limits in Table 2 to this subpart or the emission limits in Table 15 to this subpart until you must comply with the emission limits in Table 2.
(2) You must meet each operating limit in Table 4 to this subpart that applies to your boiler or process heater. If you use a control device or combination of control devices not covered in Table 4 to this subpart, or you wish to establish and monitor an alternative operating limit or an alternative monitoring parameter, you must apply to the EPA Administrator for approval of alternative monitoring under § 63.8(f).
(3) At all times, you must operate and maintain any affected source (as defined in § 63.7490), including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator that may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source.
(b) As provided in § 63.6(g), EPA may approve use of an alternative to the work practice standards in this section.
(c) Limited-use boilers and process heaters must complete a tune-up every 5 years as specified in § 63.7540. They are not subject to the emission limits in Tables 1 and 2 or Tables 11 through 15 to this subpart, the annual tune-up, or the energy assessment requirements in Table 3 to this subpart, or the operating limits in Table 4 to this subpart.
(d) Boilers and process heaters with a heat input capacity of less than or equal to 5 million Btu per hour in the units designed to burn gas 2 (other) fuels subcategory or units designed to burn light liquid fuels subcategory must complete a tune-up every 5 years as specified in § 63.7540.
(e) Boilers and process heaters in the units designed to burn gas 1 fuels subcategory with a heat input capacity of less than or equal to 5 million Btu per hour must complete a tune-up every 5 years as specified in § 63.7540. Boilers and process heaters in the units designed to burn gas 1 fuels subcategory with a heat input capacity greater than 5 million Btu per hour and less than 10 million Btu per hour must complete a tune-up every 2 years as specified in § 63.7540. Boilers and process heaters in the units designed to burn gas 1 fuels subcategory are not subject to the emission limits in Tables 1 and 2 or Tables 11 through 15 to this subpart, or the operating limits in Table 4 to this subpart.
(f) These standards apply at all times the affected unit is operating, except during periods of startup and shutdown during which time you must comply only with items 5 and 6 of Table 3 to this subpart.
§ 63.7501   [Reserved]
§ 63.7505   What are my general requirements for complying with this subpart?
(a) You must be in compliance with the emission limits, work practice standards, and operating limits in this subpart. These emission and operating limits apply to you at all times the affected unit is operating except for the periods noted in § 63.7500(f).
(b) [Reserved]
(c) You must demonstrate compliance with all applicable emission limits using performance stack testing, fuel analysis, or continuous monitoring systems (CMS), including a continuous emission monitoring system (CEMS), continuous opacity monitoring system (COMS), continuous parameter monitoring system (CPMS), or particulate matter continuous parameter monitoring system (PM CPMS), where applicable. You may demonstrate compliance with the applicable emission limit for hydrogen chloride (HCl), mercury, or total selected metals (TSM) using fuel analysis if the emission rate calculated according to § 63.7530(c) is less than the applicable emission limit. For gaseous fuels, you may not use fuel analyses to comply with the TSM alternative standard or the HCl standard. Otherwise, you must demonstrate compliance for HCl, mercury, or TSM using performance stack testing, if subject to an applicable emission limit listed in Table 1 or 2 or Tables 11 through 15 to this subpart.
(d) If you demonstrate compliance with any applicable emission limit through performance testing and subsequent compliance with operating limits through the use of CPMS, or with a CEMS or COMS, you must develop a site-specific monitoring plan according to the requirements in paragraphs (d)(1) through (4) of this section for the use of any CEMS, COMS, or CPMS. This requirement also applies to you if you petition the EPA Administrator for alternative monitoring parameters under § 63.8(f).
(1) For each CMS required in this section (including CEMS, COMS, or CPMS), you must develop, and submit to the Administrator for approval upon request, a site-specific monitoring plan that addresses design, data collection, and the quality assurance and quality control elements outlined in § 63.8(d) and the elements described in paragraphs (d)(1)(i) through (iii) of this section. You must submit this site-specific monitoring plan, if requested, at least 60 days before your initial performance evaluation of your CMS. This requirement to develop and submit a site specific monitoring plan does not apply to affected sources with existing CEMS or COMS operated according to the performance specifications under appendix B to part 60 of this chapter and that meet the requirements of § 63.7525. Using the process described in § 63.8(f)(4), you may request approval of alternative monitoring system quality assurance and quality control procedures in place of those specified in this paragraph and, if approved, include the alternatives in your site-specific monitoring plan.
(i) Installation of the CMS sampling probe or other interface at a measurement location relative to each affected process unit such that the measurement is representative of control of the exhaust emissions (e.g., on or downstream of the last control device);
(ii) Performance and equipment specifications for the sample interface, the pollutant concentration or parametric signal analyzer, and the data collection and reduction systems; and
(iii) Performance evaluation procedures and acceptance criteria (e.g., calibrations, accuracy audits, analytical drift).
(2) In your site-specific monitoring plan, you must also address paragraphs (d)(2)(i) through (iii) of this section.
(i) Ongoing operation and maintenance procedures in accordance with the general requirements of § 63.8(c)(1)(ii), (c)(3), and (c)(4)(ii);
(ii) Ongoing data quality assurance procedures in accordance with the general requirements of § 63.8(d); and
(iii) Ongoing recordkeeping and reporting procedures in accordance with the general requirements of § 63.10(c) (as applicable in Table 10 to this subpart), (e)(1), and (e)(2)(i).
(3) You must conduct a performance evaluation of each CMS in accordance with your site-specific monitoring plan.
(4) You must operate and maintain the CMS in continuous operation according to the site-specific monitoring plan.
(e) If you have an applicable emission limit, and you choose to comply using definition (2) of “startup” in § 63.7575, you must develop and implement a written startup and shutdown plan (SSP) according to the requirements in Table 3 to this subpart. The SSP must be maintained onsite and available upon request for public inspection.
§ 63.7510   What are my initial compliance requirements and by what date must I conduct them?
(a) For each boiler or process heater that is required or that you elect to demonstrate compliance with any of the applicable emission limits in Table 1 or 2 or Tables 11 through 15 to this subpart through performance (stack) testing, your initial compliance requirements include all the following:
(1) Conduct performance tests according to § 63.7520 and Table 5 to this subpart.
(2) Conduct a fuel analysis for each type of fuel burned in your boiler or process heater according to § 63.7521 and Table 6 to this subpart, except as specified in paragraphs (a)(2)(i) through (iii) of this section.
(i) For each boiler or process heater that burns a single type of fuel, you are not required to conduct a fuel analysis for each type of fuel burned in your boiler or process heater according to § 63.7521 and Table 6 to this subpart. For purposes of this subpart, units that use a supplemental fuel only for startup, unit shutdown, and transient flame stability purposes still qualify as units that burn a single type of fuel, and the supplemental fuel is not subject to the fuel analysis requirements under § 63.7521 and Table 6 to this subpart.
(ii) When natural gas, refinery gas, or other gas 1 fuels are co-fired with other fuels, you are not required to conduct a fuel analysis of those Gas 1 fuels according to § 63.7521 and Table 6 to this subpart. If gaseous fuels other than natural gas, refinery gas, or other gas 1 fuels are co-fired with other fuels and those non-Gas 1 gaseous fuels are subject to another subpart of this part, part 60, part 61, or part 65, you are not required to conduct a fuel analysis of those non-Gas 1 fuels according to § 63.7521 and Table 6 to this subpart.
(iii) You are not required to conduct a chlorine fuel analysis for any gaseous fuels. You must conduct a fuel analysis for mercury on gaseous fuels unless the fuel is exempted in paragraphs (a)(2)(i) and (ii) of this section.
(3) Establish operating limits according to § 63.7530 and Table 7 to this subpart.
(4) Conduct CMS performance evaluations according to § 63.7525.
(b) For each boiler or process heater that you elect to demonstrate compliance with the applicable emission limits in Table 1 or 2 or Tables 11 through 15 to this subpart for HCl, mercury, or TSM through fuel analysis, your initial compliance requirement is to conduct a fuel analysis for each type of fuel burned in your boiler or process heater according to § 63.7521 and Table 6 to this subpart and establish operating limits according to § 63.7530 and Table 8 to this subpart. The fuels described in paragraphs (a)(2)(i) and (ii) of this section are exempt from these fuel analysis and operating limit requirements. The fuels described in paragraph (a)(2)(ii) of this section are exempt from the chloride fuel analysis and operating limit requirements. Boilers and process heaters that use a CEMS for mercury or HCl are exempt from the performance testing and operating limit requirements specified in paragraph (a) of this section for the HAP for which CEMS are used.
(c) If your boiler or process heater is subject to a carbon monoxide (CO) limit, your initial compliance demonstration for CO is to conduct a performance test for CO according to Table 5 to this subpart or conduct a performance evaluation of your continuous CO monitor, if applicable, according to § 63.7525(a). Boilers and process heaters that use a CO CEMS to comply with the applicable alternative CO CEMS emission standard listed in Table 1 or 2 or Tables 11 through 15 to this subpart, as specified in § 63.7525(a), are exempt from the initial CO performance testing and oxygen concentration operating limit requirements specified in paragraph (a) of this section.
(d) If your boiler or process heater is subject to a PM limit, your initial compliance demonstration for PM is to conduct a performance test in accordance with § 63.7520 and Table 5 to this subpart.
(e) For existing affected sources (as defined in § 63.7490), you must complete the initial compliance demonstrations, as specified in paragraphs (a) through (d) of this section, no later than 180 days after the compliance date that is specified for your source in § 63.7495 and according to the applicable provisions in § 63.7(a)(2) as cited in Table 10 to this subpart, except as specified in paragraph (j) of this section. You must complete an initial tune-up by following the procedures described in § 63.7540(a)(10)(i) through (vi) no later than the compliance date specified in § 63.7495, except as specified in paragraph (j) of this section. You must complete the one-time energy assessment specified in Table 3 to this subpart no later than the compliance date specified in § 63.7495.
(f) For new or reconstructed affected sources (as defined in § 63.7490), you must complete the initial compliance demonstration with the emission limits no later than July 30, 2013, or within 180 days after startup of the source, whichever is later.
(1) If you are demonstrating compliance with an emission limit in Tables 11 through 13 to this subpart that is less stringent than the applicable emission limit in Table 14 to this subpart, you must demonstrate compliance with the applicable emission limit in Table 14 no later than July 29, 2016.
(2) If you are demonstrating compliance with an emission limit in Table 14 to this subpart that is less stringent than the applicable emission limit in Table 1 to this subpart, you must demonstrate compliance with the applicable emission limit in Table 1 no later than October 6, 2025.
(g) For new or reconstructed affected sources (as defined in § 63.7490), you must demonstrate initial compliance with the applicable work practice standards in Table 3 to this subpart within the applicable annual, biennial, or 5-year schedule as specified in § 63.7515(d) following the initial compliance date specified in § 63.7495(a). Thereafter, you are required to complete the applicable annual, biennial, or 5-year tune-up as specified in § 63.7515(d).
(h) For affected sources (as defined in § 63.7490) that ceased burning solid waste consistent with § 63.7495(e) and for which the initial compliance date has passed, you must demonstrate compliance within 60 days of the effective date of the waste-to-fuel switch. If you have not conducted your compliance demonstration for this subpart within the previous 12 months, you must complete all compliance demonstrations for this subpart before you commence or recommence combustion of solid waste.
(i) For an existing EGU that becomes subject after January 31, 2016, you must demonstrate compliance within 180 days after becoming an affected source.
(j) For existing affected sources (as defined in § 63.7490) that have not operated between the effective date of the rule and the compliance date that is specified for your source in § 63.7495, you must complete the initial compliance demonstration, if subject to the emission limits in Table 2 or 14 to this subpart, as applicable, as specified in paragraphs (a) through (d) of this section, no later than 180 days after the re-start of the affected source and according to the applicable provisions in § 63.7(a)(2) as cited in Table 10 to this subpart. You must complete an initial tune-up by following the procedures described in § 63.7540(a)(10)(i) through (vi) no later than 30 days after the re-start of the affected source and, if applicable, complete the one-time energy assessment specified in Table 3 to this subpart, no later than the compliance date specified in § 63.7495.
(k) For affected sources, as defined in § 63.7490, that switch subcategories consistent with § 63.7545(h) after the initial compliance date, you must demonstrate compliance within 60 days of the effective date of the switch, unless you had previously conducted your compliance demonstration for this subcategory within the previous 12 months.
§ 63.7515   When must I conduct subsequent performance tests, fuel analyses, or tune-ups?
(a) You must conduct all applicable performance tests according to § 63.7520 on an annual basis, except as specified in paragraphs (b) through (e), (g), and (h) of this section. Annual performance tests must be completed no more than 13 months after the previous performance test, except as specified in paragraphs (b) through (e), (g), and (h) of this section.
(b) If your performance tests for a given pollutant for at least 2 consecutive years show that your emissions are at or below 75 percent of the emission limit (or, in limited instances as specified in Tables 1 and 2 or 11 through 15 to this subpart, at or below the emission limit) for the pollutant, and if there are no changes in the operation of the individual boiler or process heater or air pollution control equipment that could increase emissions, you may choose to conduct performance tests for the pollutant every third year. Each such performance test must be conducted no more than 37 months after the previous performance test. If you elect to demonstrate compliance using emission averaging under § 63.7522, you must continue to conduct performance tests annually. The requirement to test at maximum chloride input level is waived unless the stack test is conducted for HCl. The requirement to test at maximum mercury input level is waived unless the stack test is conducted for mercury. The requirement to test at maximum TSM input level is waived unless the stack test is conducted for TSM.
(c) If a performance test shows emissions exceeded the emission limit or 75 percent of the emission limit (as specified in Tables 1 and 2 or 11 through 15 to this subpart) for a pollutant, you must conduct annual performance tests for that pollutant until all performance tests over a consecutive 2-year period meet the required level (at or below 75 percent of the emission limit, as specified in Tables 1 and 2 or 11 through 15).
(d) If you are required to meet an applicable tune-up work practice standard, you must conduct an annual, biennial, or 5-year performance tune-up according to § 63.7540(a)(10), (11), or (12), respectively. Each annual tune-up specified in § 63.7540(a)(10) must be no more than 13 months after the previous tune-up. Each biennial tune-up specified in § 63.7540(a)(11) must be conducted no more than 25 months after the previous tune-up. Each 5-year tune-up specified in § 63.7540(a)(12) must be conducted no more than 61 months after the previous tune-up. For a new or reconstructed affected source (as defined in § 63.7490), the first annual, biennial, or 5-year tune-up must be no later than 13 months, 25 months, or 61 months, respectively, after April 1, 2013 or the initial startup of the new or reconstructed affected source, whichever is later.
(e) If you demonstrate compliance with the mercury, HCl, or TSM based on fuel analysis, you must conduct a monthly fuel analysis according to § 63.7521 for each type of fuel burned that is subject to an emission limit in Table 1 or 2 or Tables 11 through 15 to this subpart. You may comply with this monthly requirement by completing the fuel analysis any time within the calendar month as long as the analysis is separated from the previous analysis by at least 14 calendar days. If you burn a new type of fuel, you must conduct a fuel analysis before burning the new type of fuel in your boiler or process heater. You must still meet all applicable continuous compliance requirements in § 63.7540. If each of 12 consecutive monthly fuel analyses demonstrates 75 percent or less of the compliance level, you may decrease the fuel analysis frequency to quarterly for that fuel. If any quarterly sample exceeds 75 percent of the compliance level or you begin burning a new type of fuel, you must return to monthly monitoring for that fuel, until 12 months of fuel analyses are again less than 75 percent of the compliance level. If sampling is conducted on 1 day per month, samples should be no less than 14 days apart, but if multiple samples are taken per month, the 14-day restriction does not apply.
(f) You must report the results of performance tests and the associated fuel analyses within 60 days after the completion of the performance tests. This report must also verify that the operating limits for each boiler or process heater have not changed or provide documentation of revised operating limits established according to § 63.7530 and Table 7 to this subpart, as applicable. The reports for all subsequent performance tests must include all applicable information required in § 63.7550.
(g) For affected sources (as defined in § 63.7490) that have not operated since the previous compliance demonstration and more than 1 year has passed since the previous compliance demonstration, you must complete the subsequent compliance demonstration, if subject to the emission limits in Table 1 or 2 or Tables 11 through 15 to this subpart, no later than 180 days after the re-start of the affected source and according to the applicable provisions in § 63.7(a)(2) as cited in Table 10 to this subpart. You must complete a subsequent tune-up by following the procedures described in § 63.7540(a)(10)(i) through (vi) and the schedule described in § 63.7540(a)(13) for units that are not operating at the time of their scheduled tune-up.
(h) If your affected boiler or process heater is in the unit designed to burn light liquid subcategory and you combust ultra-low sulfur liquid fuel, you do not need to conduct further performance tests (stack tests or fuel analyses) if the pollutants measured during the initial compliance performance tests meet the emission limits in Tables 1 or 2 of this subpart providing you demonstrate ongoing compliance with the emissions limits by monitoring and recording the type of fuel combusted on a monthly basis. If you intend to use a fuel other than ultra-low sulfur liquid fuel, natural gas, refinery gas, or other gas 1 fuel, you must conduct new performance tests within 60 days of burning the new fuel type.
(i) If you operate a CO CEMS that meets the Performance Specifications outlined in § 63.7525(a)(3) to demonstrate compliance with the applicable alternative CO CEMS emission standard listed in Table 1 or 2 or Tables 11 through 15 to this subpart, you are not required to conduct CO performance tests and are not subject to the oxygen concentration operating limit requirement specified in § 63.7510(a).
§ 63.7520   What stack tests and procedures must I use?
(a) You must conduct all performance tests according to § 63.7(c), (d), (f), and (h). You must also develop a site-specific stack test plan according to the requirements in § 63.7(c). You shall conduct all performance tests under such conditions as the Administrator specifies to you based on the representative performance of each boiler or process heater for the period being tested. Upon request, you shall make available to the Administrator such records as may be necessary to determine the conditions of the performance tests.
(b) You must conduct each performance test according to the requirements in Table 5 to this subpart.
(c) You must conduct each performance test under the specific conditions listed in Tables 5 and 7 to this subpart. You must conduct performance tests at representative operating load conditions while burning the type of fuel or mixture of fuels that has the highest content of chlorine and mercury, and TSM if you are opting to comply with the TSM alternative standard and you must demonstrate initial compliance and establish your operating limits based on these performance tests. These requirements could result in the need to conduct more than one performance test. Following each performance test and until the next performance test, you must comply with the operating limit for operating load conditions specified in Table 4 to this subpart.
(d) You must conduct a minimum of three separate test runs for each performance test required in this section, as specified in § 63.7(e)(3). Each test run must comply with the minimum applicable sampling times or volumes specified in Tables 1 and 2 or 11 through 15 to this subpart.
(e) To determine compliance with the emission limits, you must use the F-Factor methodology and equations in sections 12.2 and 12.3 of EPA Method 19 at 40 CFR part 60, appendix A-7 of this chapter to convert the measured particulate matter (PM) concentrations, the measured HCl concentrations, the measured mercury concentrations, and the measured TSM concentrations that result from the performance test to pounds per million Btu heat input emission rates.
(f) Except for a 30-day rolling average based on CEMS (or sorbent trap monitoring system) data, if measurement results for any pollutant are reported as below the method detection level (e.g., laboratory analytical results for one or more sample components are below the method defined analytical detection level), you must use the method detection level as the measured emissions level for that pollutant in calculating compliance. The measured result for a multiple component analysis (e.g., analytical values for multiple Method 29 fractions both for individual HAP metals and for total HAP metals) may include a combination of method detection level data and analytical data reported above the method detection level.
§ 63.7521   What fuel analyses, fuel specification, and procedures must I use?
(a) For solid and liquid fuels, you must conduct fuel analyses for chloride and mercury according to the procedures in paragraphs (b) through (e) of this section and Table 6 to this subpart, as applicable. For solid fuels and liquid fuels, you must also conduct fuel analyses for TSM if you are opting to comply with the TSM alternative standard. For gas 2 (other) fuels, you must conduct fuel analyses for mercury according to the procedures in paragraphs (b) through (e) of this section and Table 6 to this subpart, as applicable. For gaseous fuels, you may not use fuel analyses to comply with the TSM alternative standard or the HCl standard. For purposes of complying with this section, a fuel gas system that consists of multiple gaseous fuels collected and mixed with each other is considered a single fuel type and sampling and analysis is only required on the combined fuel gas system that will feed the boiler or process heater. Sampling and analysis of the individual gaseous streams prior to combining is not required. You are not required to conduct fuel analyses for fuels used for only startup, unit shutdown, and transient flame stability purposes. You are required to conduct fuel analyses only for fuels and units that are subject to emission limits for mercury, HCl, or TSM in Tables 1 and 2 or 11 through 15 to this subpart. Gaseous and liquid fuels are exempt from the sampling requirements in paragraphs (c) and (d) of this section.
(b) You must develop a site-specific fuel monitoring plan according to the following procedures and requirements in paragraphs (b)(1) and (2) of this section, if you are required to conduct fuel analyses as specified in § 63.7510.
(1) If you intend to use an alternative analytical method other than those required by Table 6 to this subpart, you must submit the fuel analysis plan to the Administrator for review and approval no later than 60 days before the date that you intend to conduct the initial compliance demonstration described in § 63.7510.
(2) You must include the information contained in paragraphs (b)(2)(i) through (vi) of this section in your fuel analysis plan.
(i) The identification of all fuel types anticipated to be burned in each boiler or process heater.
(ii) For each anticipated fuel type, the notification of whether you or a fuel supplier will be conducting the fuel analysis.
(iii) For each anticipated fuel type, a detailed description of the sample location and specific procedures to be used for collecting and preparing the composite samples if your procedures are different from paragraph (c) or (d) of this section. Samples should be collected at a location that most accurately represents the fuel type, where possible, at a point prior to mixing with other dissimilar fuel types.
(iv) For each anticipated fuel type, the analytical methods from Table 6, with the expected minimum detection levels, to be used for the measurement of chlorine or mercury.
(v) If you request to use an alternative analytical method other than those required by Table 6 to this subpart, you must also include a detailed description of the methods and procedures that you are proposing to use. Methods in Table 6 shall be used until the requested alternative is approved.
(vi) If you will be using fuel analysis from a fuel supplier in lieu of site-specific sampling and analysis, the fuel supplier must use the analytical methods required by Table 6 to this subpart.
(c) You must obtain composite fuel samples for each fuel type according to the procedures in paragraph (c)(1) or (2) of this section, or the methods listed in Table 6 to this subpart, or use an automated sampling mechanism that provides representative composite fuel samples for each fuel type that includes both coarse and fine material. At a minimum, for demonstrating initial compliance by fuel analysis, you must obtain three composite samples. For monthly fuel analyses, at a minimum, you must obtain a single composite sample. For fuel analyses as part of a performance stack test, as specified in § 63.7510(a), you must obtain a composite fuel sample during each performance test run.
(1) If sampling from a belt (or screw) feeder, collect fuel samples according to paragraphs (c)(1)(i) and (ii) of this section.
(i) Stop the belt and withdraw a 6-inch wide sample from the full cross-section of the stopped belt to obtain a minimum two pounds of sample. You must collect all the material (fines and coarse) in the full cross-section. You must transfer the sample to a clean plastic bag.
(ii) Each composite sample will consist of a minimum of three samples collected at approximately equal intervals during the testing period for sampling during performance stack testing.
(2) If sampling from a fuel pile or truck, you must collect fuel samples according to paragraphs (c)(2)(i) through (iii) of this section.
(i) For each composite sample, you must select a minimum of five sampling locations uniformly spaced over the surface of the pile.
(ii) At each sampling site, you must dig into the pile to a uniform depth of approximately 18 inches. You must insert a clean shovel into the hole and withdraw a sample, making sure that large pieces do not fall off during sampling; use the same shovel to collect all samples.
(iii) You must transfer all samples to a clean plastic bag for further processing.
(d) You must prepare each composite sample according to the procedures in paragraphs (d)(1) through (7) of this section.
(1) You must thoroughly mix and pour the entire composite sample over a clean plastic sheet.
(2) You must break large sample pieces (e.g., larger than 3 inches) into smaller sizes.
(3) You must make a pie shape with the entire composite sample and subdivide it into four equal parts.
(4) You must separate one of the quarter samples as the first subset.
(5) If this subset is too large for grinding, you must repeat the procedure in paragraph (d)(3) of this section with the quarter sample and obtain a one-quarter subset from this sample.
(6) You must grind the sample in a mill.
(7) You must use the procedure in paragraph (d)(3) of this section to obtain a one-quarter subsample for analysis. If the quarter sample is too large, subdivide it further using the same procedure.
(e) You must determine the concentration of pollutants in the fuel (mercury and/or chlorine and/or TSM) in units of pounds per million Btu of each composite sample for each fuel type according to the procedures in Table 6 to this subpart, for use in Equations 7, 8, and 9 of this subpart.
(f) To demonstrate that a gaseous fuel other than natural gas or refinery gas qualifies as an other gas 1 fuel, as defined in § 63.7575, you must conduct a fuel specification analyses for mercury according to the procedures in paragraphs (g) through (i) of this section and Table 6 to this subpart, as applicable, except as specified in paragraph (f)(1) through (4) of this section, or as an alternative where fuel specification analysis is not practical, you must measure mercury concentration in the exhaust gas when firing only the gaseous fuel to be demonstrated as an other gas 1 fuel in the boiler or process heater according to the procedures in Table 6 to this subpart.
(1) You are not required to conduct the fuel specification analyses in paragraphs (g) through (i) of this section for natural gas or refinery gas.
(2) You are not required to conduct the fuel specification analyses in paragraphs (g) through (i) of this section for gaseous fuels that are subject to another subpart of this part, part 60, part 61, or part 65.
(3) You are not required to conduct the fuel specification analyses in paragraphs (g) through (i) of this section on gaseous fuels for units that are complying with the limits for units designed to burn gas 2 (other) fuels.
(4) You are not required to conduct the fuel specification analyses in paragraphs (g) through (i) of this section for gas streams directly derived from natural gas at natural gas production sites or natural gas plants.
(g) You must develop a site-specific fuel analysis plan for other gas 1 fuels according to the following procedures and requirements in paragraphs (g)(1) and (2) of this section.
(1) If you intend to use an alternative analytical method other than those required by Table 6 to this subpart, you must submit the fuel analysis plan to the Administrator for review and approval no later than 60 days before the date that you intend to conduct the initial compliance demonstration described in § 63.7510.
(2) You must include the information contained in paragraphs (g)(2)(i) through (vi) of this section in your fuel analysis plan.
(i) The identification of all gaseous fuel types other than those exempted from fuel specification analysis under (f)(1) through (3) of this section anticipated to be burned in each boiler or process heater.
(ii) For each anticipated fuel type, the identification of whether you or a fuel supplier will be conducting the fuel specification analysis.
(iii) For each anticipated fuel type, a detailed description of the sample location and specific procedures to be used for collecting and preparing the samples if your procedures are different from the sampling methods contained in Table 6 to this subpart. Samples should be collected at a location that most accurately represents the fuel type, where possible, at a point prior to mixing with other dissimilar fuel types. If multiple boilers or process heaters are fueled by a common fuel stream it is permissible to conduct a single gas specification at the common point of gas distribution.
(iv) For each anticipated fuel type, the analytical methods from Table 6 to this subpart, with the expected minimum detection levels, to be used for the measurement of mercury.
(v) If you request to use an alternative analytical method other than those required by Table 6 to this subpart, you must also include a detailed description of the methods and procedures that you are proposing to use. Methods in Table 6 to this subpart shall be used until the requested alternative is approved.
(vi) If you will be using fuel analysis from a fuel supplier in lieu of site-specific sampling and analysis, the fuel supplier must use the analytical methods required by Table 6 to this subpart. When using a fuel supplier's fuel analysis, the owner or operator is not required to submit the information in § 63.7521(g)(2)(iii).
(h) You must obtain a single fuel sample for each fuel type for fuel specification of gaseous fuels.
(i) You must determine the concentration in the fuel of mercury, in units of microgram per cubic meter, dry basis, of each sample for each other gas 1 fuel type according to the procedures in Table 6 to this subpart.
§ 63.7522   Can I use emissions averaging to comply with this subpart?
(a) As an alternative to meeting the requirements of § 63.7500 for PM (or TSM), HCl, or mercury on a boiler or process heater-specific basis, if you have more than one existing boiler or process heater in any subcategories located at your facility, you may demonstrate compliance by emissions averaging, if your averaged emissions are not more than 90 percent of the applicable emission limit, according to the procedures in this section. You may not include new boilers or process heaters in an emissions average.
(b) For a group of two or more existing boilers or process heaters in the same subcategory that each vent to a separate stack, you may average PM (or TSM), HCl, or mercury emissions among existing units to demonstrate compliance with the limits in Table 2 or 15 to this subpart as specified in paragraphs (b)(1) through (3) of this section, if you satisfy the requirements in paragraphs (c) through (g) of this section.
(1) You may average units using a CEMS or PM CPMS for demonstrating compliance.
(2) For mercury and HCl, averaging is allowed as follows:
(i) You may average among units in any of the solid fuel subcategories.
(ii) You may average among units in any of the liquid fuel subcategories.
(iii) You may average among units in a subcategory of units designed to burn gas 2 (other) fuels.
(iv) You may not average across the units designed to burn liquid, units designed to burn solid fuel, and units designed to burn gas 2 (other) subcategories.
(3) For PM (or TSM), averaging is only allowed between units within each of the following subcategories and you may not average across subcategories:
(i) Units designed to burn coal/solid fossil fuel.
(ii) Stokers/sloped grate/other units designed to burn kiln dried biomass/bio-based solids.
(iii) Stokers/sloped grate/other units designed to burn wet biomass/bio-based solids.
(iv) Fluidized bed units designed to burn biomass/bio-based solid.
(v) Suspension burners designed to burn biomass/bio-based solid.
(vi) Dutch ovens/pile burners designed to burn biomass/bio-based solid.
(vii) Fuel Cells designed to burn biomass/bio-based solid.
(viii) Hybrid suspension/grate burners designed to burn wet biomass/bio-based solid.
(ix) Units designed to burn heavy liquid fuel.
(x) Units designed to burn light liquid fuel.
(xi) Units designed to burn liquid fuel that are non-continental units.
(xii) Units designed to burn gas 2 (other) gases.
(c) For each existing boiler or process heater in the averaging group, the emission rate achieved during the initial compliance test for the HAP being averaged must not exceed the emission level that was being achieved on April 1, 2013 or the control technology employed during the initial compliance test must not be less effective for the HAP being averaged than the control technology employed on April 1, 2013.
(d) The averaged emissions rate from the existing boilers and process heaters participating in the emissions averaging option must not exceed 90 percent of the limits in Table 2 or 15 to this subpart at all times the affected units are subject to numeric emission limits following the compliance date specified in § 63.7495.
(e) You must demonstrate initial compliance according to paragraph (e)(1) or (2) of this section using the maximum rated heat input capacity or maximum steam generation capacity of each unit and the results of the initial performance tests or fuel analysis.
(1) You must use Equation 1a or 1b or 1c to this paragraph (e)(1) to demonstrate that the PM (or TSM), HCl, or mercury emissions from all existing units participating in the emissions averaging option for that pollutant do not exceed the emission limits in Table 2 or 15 to this subpart. Use Equation 1a if you are complying with the emission limits on a heat input basis, use Equation 1b if you are complying with the emission limits on a steam generation (output) basis, and use Equation 1c if you are complying with the emission limits on a electric generation (output) basis.
(2) If you are not capable of determining the maximum rated heat input capacity of one or more boilers that generate steam, you may use Equation 2 to this paragraph (e)(2) as an alternative to using Equation 1a of paragraph (e)(1) of this section to demonstrate that the PM (or TSM), HCl, or mercury emissions from all existing units participating in the emissions averaging option do not exceed the emission limits for that pollutant in Table 2 or 15 to this subpart that are in pounds per million Btu of heat input.
(f) After the initial compliance demonstration described in paragraph (e) of this section, you must demonstrate compliance on a monthly basis determined at the end of every month (12 times per year) according to paragraphs (f)(1) through (3) of this section. The first monthly period begins on the compliance date specified in § 63.7495. If the affected source elects to collect monthly data for up the 11 months preceding the first monthly period, these additional data points can be used to compute the 12-month rolling average in paragraph (f)(3) of this section.
(1) For each calendar month, you must use Equation 3a or 3b or 3c of this section to calculate the average weighted emission rate for that month. Use Equation 3a and the actual heat input for the month for each existing unit participating in the emissions averaging option if you are complying with emission limits on a heat input basis. Use Equation 3b and the actual steam generation for the month if you are complying with the emission limits on a steam generation (output) basis. Use Equation 3c and the actual electrical generation for the month if you are complying with the emission limits on an electrical generation (output) basis.
(2) If you are not capable of monitoring heat input, you may use Equation 4 of this section as an alternative to using Equation 3a of this section to calculate the average weighted emission rate using the actual steam generation from the boilers participating in the emissions averaging option.
(3) Until 12 monthly weighted average emission rates have been accumulated, calculate and report only the average weighted emission rate determined under paragraph (f)(1) or (2) of this section for each calendar month. After 12 monthly weighted average emission rates have been accumulated, for each subsequent calendar month, use Equation 5 of this section to calculate the 12-month rolling average of the monthly weighted average emission rates for the current calendar month and the previous 11 calendar months.
(g) You must develop, and submit upon request to the applicable Administrator for review and approval, an implementation plan for emission averaging according to the following procedures and requirements in paragraphs (g)(1) through (4) of this section.
(1) If requested, you must submit the implementation plan no later than 180 days before the date that the facility intends to demonstrate compliance using the emission averaging option.
(2) You must include the information contained in paragraphs (g)(2)(i) through (vii) of this section in your implementation plan for all emission sources included in an emissions average:
(i) The identification of all existing boilers and process heaters in the averaging group, including for each either the applicable HAP emission level or the control technology installed as of January 31, 2013 and the date on which you are requesting emission averaging to commence;
(ii) The process parameter (heat input or steam generated) that will be monitored for each averaging group;
(iii) The specific control technology or pollution prevention measure to be used for each emission boiler or process heater in the averaging group and the date of its installation or application. If the pollution prevention measure reduces or eliminates emissions from multiple boilers or process heaters, the owner or operator must identify each boiler or process heater;
(iv) The test plan for the measurement of PM (or TSM), HCl, or mercury emissions in accordance with the requirements in § 63.7520;
(v) The operating parameters to be monitored for each control system or device consistent with § 63.7500 and Table 4, and a description of how the operating limits will be determined;
(vi) If you request to monitor an alternative operating parameter pursuant to § 63.7525, you must also include:
(A) A description of the parameter(s) to be monitored and an explanation of the criteria used to select the parameter(s); and
(B) A description of the methods and procedures that will be used to demonstrate that the parameter indicates proper operation of the control device; the frequency and content of monitoring, reporting, and recordkeeping requirements; and a demonstration, to the satisfaction of the Administrator, that the proposed monitoring frequency is sufficient to represent control device operating conditions; and
(vii) A demonstration that compliance with each of the applicable emission limit(s) will be achieved under representative operating load conditions. Following each compliance demonstration and until the next compliance demonstration, you must comply with the operating limit for operating load conditions specified in Table 4 to this subpart.
(3) If submitted upon request, the Administrator shall review and approve or disapprove the plan according to the following criteria:
(i) Whether the content of the plan includes all of the information specified in paragraph (g)(2) of this section; and
(ii) Whether the plan presents sufficient information to determine that compliance will be achieved and maintained.
(4) The applicable Administrator shall not approve an emission averaging implementation plan containing any of the following provisions:
(i) Any averaging between emissions of differing pollutants or between differing sources; or
(ii) The inclusion of any emission source other than an existing unit in the same subcategories.
(h) For a group of two or more existing affected units, each of which vents through a single common stack, you may average PM (or TSM), HCl, or mercury emissions to demonstrate compliance with the limits for that pollutant in Table 2 or 15 to this subpart if you satisfy the requirements in paragraph (i) or (j) of this section.
(i) For a group of two or more existing units in the same subcategory, each of which vents through a common emissions control system to a common stack, that does not receive emissions from units in other subcategories or categories, you may treat such averaging group as a single existing unit for purposes of this subpart and comply with the requirements of this subpart as if the group were a single unit.
(j) For all other groups of units subject to the common stack requirements of paragraph (h) of this section, including situations where the exhaust of affected units are each individually controlled and then sent to a common stack, the owner or operator may elect to:
(1) Conduct performance tests according to procedures specified in § 63.7520 in the common stack if affected units from other subcategories vent to the common stack. The emission limits that the group must comply with are determined by the use of Equation 6 to this paragraph (j)(1).
(2) Conduct performance tests according to procedures specified in § 63.7520 in the common stack. If affected units and non-affected units vent to the common stack, the non-affected units must be shut down or vented to a different stack during the performance test unless the facility determines to demonstrate compliance with the non-affected units venting to the stack; and
(3) Meet the applicable operating limit specified in § 63.7540 and Table 8 to this subpart for each emissions control system (except that, if each unit venting to the common stack has an applicable opacity operating limit, then a single continuous opacity monitoring system may be located in the common stack instead of in each duct to the common stack).
(k) The common stack of a group of two or more existing boilers or process heaters in the same subcategories subject to paragraph (h) of this section may be treated as a separate stack for purposes of paragraph (b) of this section and included in an emissions averaging group subject to paragraph (b) of this section.