For the reasons stated in the preamble, title 40, chapter I,

part 63 of the Code of Federal Regulations is amended as follows:

Part 63    [ AMENDED]

1. The authority citation for part 63 continues to read as follows:

Authority: 42 U. S. C. 7401, et seq.

SUBPART A   [ AMENDED}

2. Section 63.14 is amended by adding paragraphs ( b)( 30) through ( 46) and paragraph ( i)( 4). The additions read as follows:

§ 63.14 Incorporation by Reference.

* * * * *

( b) * * *

( 30) ASTM Method D388 99e1, Standard Classification of Coals by Rank, IBR approved for § 63.7575.

( 31) ASTM D396 02a, Standard Specification for Fuel Oils, IBR approved for § 63.7575.

( 32) ASTM D1835 03a, Standard Specification for Liquified Petroleum ( LP) Gases, IBR approved for § 63.7575.

( 33) ASTM D2013 01, Standard Practice for Preparing Coal Samples for Analysis, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 34) ASTM D2234/ D2234M 03, Standard Practice for Collection of a Gross Sample of Coal, IBR approved for Table 2 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 35) ASTM D3173 02, Standard Test Method for Moisture in the Analysis Sample of Coal and Coke, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 36) ASTM D3683 94 ( 2000), Standard Test Method for Trace Elements in Coal and Coke Ash Absorption, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 37) ASTM D3684 01, Standard Test Method for Total Mercury in Coal by the Oxygen Bomb Combustion/ Atomic Absorption Method, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 38) ASTM D5198 92 ( 2003), Standard Practice for Nitric Acid Digestion of Solid Waste, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 39) ASTM D5865 03a, Standard Test Method for Gross Calorific Value of Coal and Coke, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 40) ASTM D6323 98 ( 2003), Standard Guide for Laboratory Subsampling of Media Related to Waste Management Activities, IBR approved for Table 6 to Subpart DDDDD of 3 Part 63   Requirements for Fuel Analysis Testing.

( 41) ASTM D6522 00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for Table 5 to Subpart DDDDD of Part 63   Requirements for Performance Tests.

( 42) ASTM D6784 02, Standard Test Method for Elemental, Oxidized, Particle Bound and Total Mercury in Flue Gas Generated from Coal Fired Stationary Sources ( Ontario Hydro Method), IBR approved for Table 5 to Subpart DDDDD of Part 63   Requirements for Performance Tests.

( 43) ASTM E711 87 ( 1996), Standard Test Method for Gross Calorific Value of Refuse Derived Fuel by the Bomb Calorimeter, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 44) ASTM E776 87 ( 1996), Standard Test Method for Forms of Chlorine in Refuse Derived Fuel, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

( 45) ASTM E871 82 ( 1998), Standard Method of Moisture Analysis of Particulate Wood Fuels, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing. 4 ( 46) ASTM E885 88 ( 1996), Standard Test Methods for Analyses of Metals in Refuse Derived Fuel by Atomic Absorption Spectroscopy, IBR approved for Table 6 to Subpart DDDDD of Part 63   Requirements for Fuel Analysis Testing.

* * * * *

( i) * * *

( 4) ASME PTC 19.10 1981, Flue Gas Exhaust Gas Analyses  Part 10, IBR approved for Table 5 to Subpart DDDDD of Part 63  Performance Testing Requirements.

3. Part 63 is amended by adding subpart DDDDD to read as follows:

Subpart DDDDD National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers and Process Heaters Sec.

What this Subpart Covers 63.7480 What is the purpose of this subpart? 63.7485 Am I subject to this subpart? 63.7490 What is the affected source of this subpart? 63.7491 Are any boilers or process heaters exempt from this subpart? 63.7495 When do I have to comply with this subpart?

Emission Limits and Work Practice Standards 63.7499 What are the subcategories of boilers and process heaters? 63.7500 What emission limits, work practice standards, and operating limits must I meet?

General Compliance Requirements 63.7505 What are my general requirements for complying 5 with this subpart? 63.7506 Do any boilers or process heaters have limited requirements? 63.7507 What are the health based compliance alternatives for the HCl and total selected metals standards?

Testing, Fuel Analyses, and Initial Compliance Requirements 63.7510 What are my initial compliance requirements and by what date must I conduct them? 63.7515 When must I conduct subsequent performance tests or fuel analyses? 63.7520 What performance tests and procedures must I use? 63.7521 What fuel analyses and procedures must I use? 63.7522 Can I use emission averaging to comply with this subpart? 63.7525 What are my monitoring, installation, operation, and maintenance requirements? 63.7530 How do I demonstrate initial compliance with the emission limits and work practice standards?

Continuous Compliance Requirements 63.7535 How do I monitor and collect data to demonstrate continuous compliance? 63.7540 How do I demonstrate continuous compliance with the emission limits and work practice standards? 63.7541 How do I demonstrate continuous compliance under the emission averaging provision?

Notifications, Reports, and Records 63.7545 What notifications must I submit and when? 63.7550 What reports must I submit and when? 63.7555 What records must I keep? 63.7560 In what form and how long must I keep my records?

Other Requirements and Information 63.7565 What parts of the General Provisions apply to me? 63.7570 Who implements and enforces this subpart? 63.7575 What definitions apply to this subpart?

Tables to Subpart DDDDD of Part 63 Table 1 to Subpart DDDDD of Part 63. Emission Limits and Work Practice Standards Table 2 to Subpart DDDDD of Part 63. Operating Limits for Boilers and Process Heaters With Particulate Matter Emission Limits 6 Table 3 to Subpart DDDDD of Part 63. Operating Limits for Boilers and Process Heaters With Mercury Emission Limits and Boilers and Process Heaters That Choose to Comply With the Alternative Total Selected Metals Emission Limits Table 4 to Subpart DDDDD of Part 63. Operating Limits for Boilers and Process Heaters With Hydrogen Chloride Emission Limits Table 5 to Subpart DDDDD of Part 63. Performance Testing Requirements Table 6 to Subpart DDDDD of Part 63. Fuel Analysis Requirements Table 7 to Subpart DDDDD of Part 63. Establishing Operating Limits Table 8 to Subpart DDDDD of Part 63. Demonstrating Continuous Compliance Table 9 to Subpart DDDDD of Part 63. Reporting Requirements Table 10 to Subpart DDDDD of Part 63. Applicability of General Provisions to Subpart DDDDD What this Subpart Covers § 63.7480 What is the purpose of this subpart?

This subpart establishes national emission limits and work practice standards for hazardous air pollutants emitted from industrial, commercial, and institutional boilers and process heaters. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limits 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 hazardous air pollutants as defined in § 63.2 or § 63.760 ( 40 CFR part 63, subpart HH,

National Emission Standards for Hazardous Air Pollutants 7 from Oil and Natural Gas Production Facilities), except as specifically exempted in § 63.7491.

§ 63.7490 What is the affected source of this subpart?

( a) This subpart applies to new, reconstructed, or existing affected sources as described in paragraphs ( a)( 1)

and ( 2) of this section.

( 1) The affected source of this subpart is the collection of all existing industrial, commercial, and institutional boilers and process heaters located at a major source 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 located at a major source as defined in § 63.7575.

( b) A boiler or process heater is new if you commence construction of the boiler or process heater after January 13, 2003; 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 January 13, 2003; 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. 8 § 63.7491 Are any boilers or process heaters exempt from this subpart?

( a) The types of boilers and process heaters listed in paragraphs ( a)( 1) through ( 14) of this section are exempt from this subpart.

( 1) A municipal waste combustor covered by 40 CFR part 60, subpart AAAA, subpart BBBB or subpart Cb.

( 2) A hospital/ medical/ infectious waste incinerator covered by 40 CFR part 60, subpart Ce or subpart Ec.

( 3) An electric utility steam generating unit that is a fossil fuel fired combustion unit of more than 25 megawatts that serves a generator that produces electricity for sale. A unit that cogenerates steam and electricity, and supplies more than one third of its potential electric output capacity, and more than 25 megawatts electrical output to any utility power distribution system for sale is considered an electric utility steam generating unit.

( 4) A boiler or process heater required to have a permit under section 3005 of the Solid Waste Disposal Act or covered by 40 CFR part 63, subpart EEE ( e. g., hazardous waste boilers).

( 5) A commercial and industrial solid waste incineration unit covered by 40 CFR part 60, subpart CCCC or subpart DDDD. 9 ( 6) A recovery boiler or furnace covered by 40 CFR part 63, subpart MM.

( 7) A boiler or process heater that is used specifically for research and development. This does not include units that only provide steam to a process at a research and development facility.

( 8) A hot water heater as defined in this subpart.

( 9) A refining kettle covered by 40 CFR part 63,

subpart X.

( 10) An ethylene cracking furnace covered by 40 CFR part 63, subpart YY.

( 11) Blast furnace stoves as described in the EPA document, entitled " National Emission Standards for Hazardous Air Pollutants ( NESHAP) for Integrated Iron and Steel Plants  Background Information for Proposed Standards," ( EPA 453/ R 01 005).

( 12) Any boiler and process heater specifically listed as an affected source in another standard( s) under 40 CFR part 63.

( 13) Temporary boilers as defined in this subpart.

( 14) Blast furnace gas fuel fired boilers and process heaters 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 [ INSERT 10 THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER] 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 [ INSERT THE DATE 3 YEARS AFTER PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER].

( c) If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of hazardous air pollutants ( HAP), paragraphs ( c)( 1) and ( 2) of this section apply to you.

( 1) Any new or reconstructed boiler or process heater at the existing facility must be in compliance with this subpart upon startup.

( 2) Any existing boiler or process heater at the existing facility must be in compliance with this subpart within 3 years after the facility 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.

Emission Limits and Work Practice Standards § 63.7499 What are the subcategories of boilers and process heaters? 11 ( a) The subcategories of boilers and process heaters are large solid fuel, limited use solid fuel, small solid fuel, large liquid fuel, limited use liquid fuel, small liquid fuel, large gaseous fuel, limited use gaseous fuel,

and small gaseous fuel. Each subcategory is defined in § 63.7575.

( b) If you change an existing boiler or process heater in a solid fuel subcategory such that its applicable subcategory also changes, and the change does not meet the definition of reconstruction as defined in subpart A of this part, you may choose to meet the applicable emission limits for the original solid fuel subcategory.

§ 63.7500 What emission limits, work practice standards, and operating limits must I meet?

( a) You must meet the requirements in paragraphs ( a)( 1) and ( 2) of this section.

( 1) You must meet each emission limit and work practice standard in Table 1 to this subpart that applies to your boiler or process heater, except as provided under § 63.7507.

( 2) You must meet each operating limit in Tables 2 through 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 Tables 2 through 4 to this subpart, or you wish to establish and monitor an alternative 12 operating limit and alternative monitoring parameters, you must apply to the United States Environmental Protection Agency ( EPA) Administrator for approval of alternative monitoring under § 63.8( f).

( b) As provided in § 63.6( g), EPA may approve use of an alternative to the work practice standards in this section.

General Compliance Requirements § 63.7505 What are my general requirements for complying with this subpart?

( a) You must be in compliance with the emission limits ( including operating limits) and the work practice standards in this subpart at all times, except during periods of startup, shutdown, and malfunction.

( b) You must always operate and maintain your affected source, including air pollution control and monitoring equipment, according to the provisions in § 63.6( e)( 1)( i).

( c) You can demonstrate compliance with any applicable emission limit using fuel analysis if the emission rate calculated according to § 63.7530( d) is less than the applicable emission limit. Otherwise, you must demonstrate compliance using performance testing.

( d) If you demonstrate compliance with any applicable emission limit through performance testing, you must develop a site specific monitoring plan according to the requirements in paragraphs ( d)( 1) through ( 4) of this 13 section. This requirement also applies to you if you petition the EPA Administrator for alternative monitoring parameters under § 63.8( f).

( 1) For each continuous monitoring system ( CMS)

required in this section, you must develop and submit to the EPA Administrator for approval a site specific monitoring plan that addresses paragraphs ( d)( 1)( i) through ( iii) of this section. You must submit this site specific monitoring plan at least 60 days before your initial performance evaluation of your CMS.

( 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).

( 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 14 accordance with the general requirements of § 63.8( c)( 1),

( 3), and ( 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),

( 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) You must develop and implement a written startup,

shutdown, and malfunction plan ( SSMP) according to the provisions in § 63.6( e)( 3).

§ 63.7506 Do any boilers or process heaters have limited requirements?

( a) New or reconstructed boilers and process heaters in one of the liquid fuel subcategories ( the large liquid fuel subcategory, the limited use liquid fuel subcategory,

or the small liquid fuel subcategory) that burn only fossil fuels and other gases and do not burn any residual oil are subject to the emission limits and applicable work practice standards in Table 1 to this subpart. You are not required to conduct a performance test to demonstrate compliance with 15 the emission limits. You are not required to set and maintain operating limits to demonstrate continuous compliance with the emission limits. However, you must meet the requirements in paragraphs ( a)( 1) and ( 2) of this section.

( 1) To demonstrate initial compliance, you must include a signed statement in the Notification of Compliance Status report required in § 63.7545( e) that indicates you burn only liquid fossil fuels other than residual oils,

either alone or in combination with gaseous fuels.

( 2) To demonstrate continuous compliance with the applicable emission limits, you must also keep records that demonstrate that you burn only liquid fossil fuels other than residual oils, either alone or in combination with gaseous fuels. You must also include a signed statement in each semiannual compliance report required in § 63.7550 that indicates you burned only liquid fossil fuels other than residual oils, either alone or in combination with gaseous fuels, during the reporting period.

( b) The affected boilers and process heaters listed in paragraphs ( b)( 1) through ( 4) of this section are subject to only the initial notification requirements in § 63.9( b)

( i. e., they are not subject to the emission limits, work practice standards, performance testing, monitoring, SSMP,

site specific monitoring plans, recordkeeping and reporting 16 requirements of this subpart or any other requirements in subpart A of this part).

( 1) Existing large and limited use gaseous fuel fired units.

( 2) Existing large and limited use liquid fuel fired units.

( 3) New small gaseous fuel fired units.

( 4) New small liquid fuel fired units that burn only gaseous fuels or distillate oil. New small liquid fuelfired boilers and process heaters that commence burning of any other type of liquid fuel must comply with all applicable requirements of this subpart and subpart A of this part upon startup of burning the other type of liquid fuel.

( c) The affected boilers and process heaters listed in paragraphs ( c)( 1) through ( 3) of this section are not subject to the initial notification requirements in § 63.9( b)

and are not subject to any requirements in this subpart or in subpart A of this part ( i. e., they are not subject to the emission limits, work practice standards, performance testing, monitoring, SSM plans, site specific monitoring plans, recordkeeping and reporting requirements of this subpart, or any other requirements in subpart A of this part.

( 1) Existing small solid fuel fired boilers and 17 process heaters.

( 2) Existing small liquid fuel fired boilers and process heaters.

( 3) Existing small gaseous fuel fired boilers and process heaters.

§ 63.7507 What are the health based compliance alternatives for the hydrogen chloride ( HCl) and total selected metals ( TSM) standards?

( a) As an alternative to the requirement for large solid fuel fired boilers located at a single facility to demonstrate compliance with the HCl emission limit in Table 1 to this subpart, you may demonstrate eligibility for the health based compliance alternative for HCl emissions under the procedures prescribed in appendix A to this subpart.

( b) In lieu of complying with the TSM emission standards in Table 1 to this subpart based on the sum of emissions for the eight selected metals, you may demonstrate eligibility for complying with the TSM emission standards in Table 1 based on the sum of emissions for seven selected metals ( by excluding manganese emissions from the summation of TSM emissions) under the procedures prescribed in appendix A of this subpart.

Testing, Fuel Analyses, and Initial Compliance Requirements § 63.7510 What are my initial compliance requirements and by what date must I conduct them? 18 ( a) For affected sources that elect to demonstrate compliance with any of the emission limits of this subpart through performance testing, your initial compliance requirements include conducting performance tests according to § 63.7520 and Table 5 to this subpart, conducting 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, establishing operating limits according to § 63.7530 and Table 7 to this subpart, and conducting continuous monitoring system performance evaluations according to § 63.7525.

( b) For affected sources that elect to demonstrate compliance with the emission limits 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 7 to this subpart.

( c) For sources that have an applicable work practice standard, your initial compliance requirements depend on the rated capacity of your boiler or process heater. If your boiler or process heater has a heat input capacity less than 100 million Btu per hour, your initial compliance demonstration is conducting a performance test for carbon monoxide according to Table 5 to this subpart. If your 19 boiler or process heater has a heat input capacity of 100 million Btu per hour or greater, your initial compliance demonstration is conducting a performance evaluation of your continuous emission monitoring system for carbon monoxide according to 63.7525( a).

( d) For existing affected sources, you must demonstrate initial compliance 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.

( e) If your new or reconstructed affected source commenced construction or reconstruction between January 13,

2003 and [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must demonstrate initial compliance with either the proposed emission limits and work practice standards or the promulgated emission limits and work practice standards no later than 180 calendar days after [ INSERT THE DATE 180 DAYS AFTER PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER] or within 180 calendar days after startup of the source, whichever is later,

according to § 63.7( a)( 2)( ix).

( f) If your new or reconstructed affected source commenced construction or reconstruction between January 13,

2003, and [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], and you chose to comply with the 20 proposed emission limits and work practice standards when demonstrating initial compliance, you must conduct a second compliance demonstration for the promulgated emission limits and work practice standards within 3 years after [ INSERT THE DATE 3 YEARS AFTER PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER] or within 3 years after startup of the affected source, whichever is later.

( g) If your new or reconstructed affected source commences construction or reconstruction after [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must demonstrate initial compliance with the promulgated emission limits and work practice standards no later than 180 days after startup of the source.

§ 63.7515 When must I conduct subsequent performance tests or fuel analyses?

( a) You must conduct all applicable performance tests according to § 63.7520 on an annual basis, unless you follow the requirements listed in paragraphs ( b) through ( d) of this section. Annual performance tests must be completed between 10 and 12 months after the previous performance test, unless you follow the requirements listed in paragraphs ( b) through ( d) of this section.

( b) You can conduct performance tests less often for a given pollutant if your performance tests for the pollutant ( particulate matter, HCl, mercury, or TSM) for at least 3 21 consecutive years show that you comply with the emission limit. In this case, you do not have to conduct a performance test for that pollutant for the next 2 years.

You must conduct a performance test during the third year and no more than 36 months after the previous performance test.

( c) If your boiler or process heater continues to meet the emission limit for particulate matter, HCl, mercury, or TSM, you may choose to conduct performance tests for these pollutants every third year, but each such performance test must be conducted no more than 36 months after the previous performance test.

( d) If a performance test shows noncompliance with an emission limit for particulate matter, HCL, mercury, or TSM,

you must conduct annual performance tests for that pollutant until all performance tests over a consecutive 3 year period show compliance.

( e) If you have an applicable work practice standard for carbon monoxide and your boiler or process heater has a heat input capacity less than 100 million Btu per hour, you must conduct annual performance tests for carbon monoxide according to § 63.7520. Each annual performance test must be conducted between 10 and 12 months after the previous performance test.

( f) You must conduct a fuel analysis according to 22 § 63.7521 for each type of fuel burned no later than 5 years after the previous fuel analysis for each fuel type. 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.

( g) You must report the results of performance tests and fuel analyses within 60 days after the completion of the performance tests or fuel analyses. This report should also verify that the operating limits for your affected source have not changed or provide documentation of revised operating parameters established according to § 63.7530 and Table 7 to this subpart, as applicable. The reports for all subsequent performance tests and fuel analyses should include all applicable information required in § 63.7550.

§ 63.7520 What performance 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 test plan according to the requirements in § 63.7( c) if you elect to demonstrate compliance through performance testing.

( b) You must conduct each performance test according to the requirements in Table 5 to this subpart.

( c) New or reconstructed boilers or process heaters in one of the liquid fuel subcategories that burn only fossil 23 fuels and other gases and do not burn any residual oil must demonstrate compliance according to § 63.7506( a).

( d) 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 the maximum normal operating load while burning the type of fuel or mixture of fuels that have the highest content of chlorine,

mercury, and total selected metals, and you must demonstrate initial compliance and establish your operating limits based on these tests. These requirements could result in the need to conduct more than one performance test.

( e) You may not conduct performance tests during periods of startup, shutdown, or malfunction.

( f) You must conduct three separate test runs for each performance test required in this section, as specified in § 63.7( e)( 3). Each test run must last at least 1 hour.

( g) 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 of appendix A to this subpart to convert the measured particulate matter concentrations, the measured HCL concentrations, the measured TSM concentrations, and the measured mercury concentrations that result from the initial performance test to pounds per million Btu heat input emission rates using F factors. 24 § 63.7521 What fuel analyses and procedures must I use?

( a) You must conduct fuel analyses according to the procedures in paragraphs ( b) through ( e) of this section and Table 6 to this subpart, as applicable.

( b) You must develop and submit a site specific fuel analysis plan to the EPA Administrator for review and approval according to the following procedures and requirements in paragraphs ( b)( 1) and ( 2) of this section.

( 1) You must submit the fuel analysis plan no later than 180 days before the date that you intend to demonstrate compliance.

( 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 fuel type, the notification of whether you or a fuel supplier will be conducting the fuel analysis.

( iii) For each 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. 25 ( iv) For each fuel type, the analytical methods, with the expected minimum detection levels, to be used for the measurement of selected total metals, 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 will be used.

( 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) At a minimum, you must obtain three composite fuel samples for each fuel type according to the procedures in paragraph ( c)( 1) or ( 2) of this section.

( 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. Collect all the material ( fines and coarse) in the full cross section. 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. 26 ( 2) If sampling from a fuel pile or truck, collect fuel samples according to paragraphs ( c)( 2)( i) through ( iii)

of this section.

( i) For each composite sample, select a minimum of five sampling locations uniformly spaced over the surface of the pile.

( ii) At each sampling site, dig into the pile to a depth of 18 inches. Insert a clean flat square shovel into the hole and withdraw a sample, making sure that large pieces do not fall off during sampling.

( iii) Transfer all samples to a clean plastic bag for further processing.

( d) Prepare each composite sample according to the procedures in paragraphs ( d)( 1) through ( 7) of this section.

( 1) Throughly mix and pour the entire composite sample over a clean plastic sheet.

( 2) Break sample pieces larger than 3 inches into smaller sizes.

( 3) Make a pie shape with the entire composite sample and subdivide it into four equal parts.

( 4) Separate one of the quarter samples as the first subset.

( 5) If this subset is too large for grinding, repeat the procedure in paragraph ( d)( 3) of this section with the quarter sample and obtain a one quarter subset from this 27 sample.

( 6) Grind the sample in a mill.

( 7) 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) Determine the concentration of pollutants in the fuel ( mercury, chlorine, and/ or total selected metals) 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.

§ 63.7522 Can I use emission averaging to comply with this subpart?

( a) As an alternative to meeting the requirements of § 63.7500, if you have more than one existing large solid fuel boiler located at your facility, you may demonstrate compliance by emission averaging according to the procedures in this section in a State that does not choose to exclude emission averaging.

( b) For purposes of emission averaging, after the effective date of this subpart if you change any existing large solid fuel boiler such that its applicable subcategory also changes, and the change does not meet the definition of reconstruction as defined in section 63.2, you may choose to meet the applicable emission limits in this subpart for the 28 original subcategory.

( c) For purposes of emission averaging, after the effective date of this subpart if you replace any existing large solid fuel boiler with a new gaseous fuel boiler, and document that the existing large solid fuel boiler is permanently shutdown, you may choose to include in the emission averaging the new gaseous fuel boiler heat input up to the maximum rated heat input capacity of the replaced large solid fuel boiler. The new gaseous fuel boiler must meet each emission limit and work practice standard in Table 1 to this subpart that applies.

( d) For each existing large solid fuel boiler 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 the effective date of the standard 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 the effective date of this subpart.

( e) You may average particulate matter or TSM, HCl,

and mercury emissions from existing large solid fuel boilers to demonstrate compliance with the limits in Table 1 to this subpart if you satisfy the requirements in paragraphs ( f)

and ( g) of this section.

( f) The weighted average emissions from the existing 29 AveWeightedEmissions Er Hm Hm i n i n = × ÷ = =

( ) 1 1 large solid fuel boilers participating in the emissions averaging option must be in compliance with the limits in Table 1 to this subpart at all times following the compliance date specified in § 63.7495.

( 1) Owners or operators must use equation 1 of this section to demonstrate that the particulate matter or TSM,

HCl, and mercury emissions from all existing large solid fuel boilers participating in the emissions averaging option do not exceed the emission limits in Table 1 of this subpart.

( Eq. 1 )

Where:

AveWeighted = A v e r a g e w e i g h t e d e m i s s i 30 AveWeightedEmissions Er Sm Cf Sm Cf i n i n = × × ÷ × = =

( ) 1 1 ons for Emissions particulate matter or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Er = Emission rate ( as calculated according to Table 5 to this subpart) or fuel analysis ( as calculated by the applicable equation in § 63.7530) for boiler, i, for particulate matter or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Hm = Maximum rated heat input capacity of boiler, i, in units of million Btu per hour. n = Number of large solid fuel boilers participating in the emissions averaging option.

( 2) If you are not capable of monitoring heat input, you can use equation 2 of this section as an alternative to using equation 1 of this section to demonstrate that the particulate matter or TSM,

HCl, and mercury emissions from all existing large solid fuel boilers participating in the emissions averaging option do not exceed the emission limits in Table 1 to this subpart.

( Eq. 2)

Where:

AveWeighted = Average weighted emission level for Emissions PM or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Er = Emission rate ( as calculated 31 AveWeightedEmissions Er Hb Hb i n i n = × ÷ = =

( ) 1 1 according to Table 5 to this subpart) or fuel analysis ( as calculated by the applicable equation in § 63.7530) for boiler, i, for particulate matter or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Sm = Maximum steam generation by boiler, i, in units of pounds. Cf = Conversion factor, calculated from the most recent compliance test, in units of million Btu of heat input per pounds of steam generated.

( g) For each calendar month, owners or operators must ensure that the heat capacity for existing large solid fuel boilers participating in the emissions averaging option does not result in an exceedance of the average weighted emission limit following the compliance date specified in § 63.7495.

( 1) For each calendar month, owners or operators must use equation 3 of this section to calculate the average weighted emission limit using the actual heat capacity for each existing large solid fuel boilers participating in the emissions averaging option.

( Eq. 3)

Where:

AveWeighted = Average weighted emission level for Emissions particulate matter or TSM, HCl, or mercury, in units of pounds per 32 million Btu of heat input. Er = Emission rate, calculated during the most recent compliance test,( as calculated according to Table 5 to this subpart) or fuel analysis ( as calculated by the applicable equation in § 63.7530) for boiler, i, for particulate matter or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Hb = The average heat input for each calendar month of boiler, i, in units of million Btu n = Number of large solid fuel boilers participating in the emissions averaging option.

( 2) If you are not capable of monitoring heat input,

you can use equation 4 of this section as an alternative to using equation 3 of this section to demonstrate that the actual steam generation from the large solid fuel boilers participating in the emissions averaging option for the calendar month does not result in an exceedance of the average weighted emission limit. 33 AveWeightedEmissions Er Sa Cf Sa Cf i n i n = × × ÷ × = =

( ) 1 1 ( Eq. 4)

Where:

AveWeighted = Average weighted emission level for Emissions PM or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Er = Emission rate, calculated during the most recent compliance test( as calculated according to Table 5 to this subpart) or fuel analysis ( as calculated by the applicable equation in § 63.7530) for boiler, i, for particulate matter or TSM, HCl, or mercury, in units of pounds per million Btu of heat input. Sa = Actual steam generation for each calender month by boiler, i, in units of pounds. Cf = Conversion factor, as calculated during the most recent compliance test, in units of million Btu of heat input per pounds of steam generated.

( h) You must develop and submit an implementation plan for emission averaging to the applicable regulatory authority for review and approval according to the following procedures and requirements in paragraphs ( h)( 1) through ( 4).

( 1) You must submit the implementation plan no later than 6 months before the date that the facility intends to demonstrate compliance using the emission averaging option. 34 ( 2) You must include the information contained in paragraphs ( 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 large solid fuel boilers in the averaging group, including for each either the applicable HAP emission level or the control technology installed on the effective date of this subpart;

( ii) The process parameter ( heat input or steam generated) that will be monitored for each averaging group of large solid fuel boilers;

( iii) The specific control technology or pollution prevention measure to be used for each emission source in the averaging group and the date of its installation or application. If the pollution prevention measure reduces or eliminates emissions from multiple sources, the owner or operator must identify each source. If the pollution prevention measure is the replacement of an existing large solid fuel boiler, the owner or operator must document that this boiler has been permanently shutdown or dismantled;

( iv) The test plan for the measurement of particulate matter ( 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 and a description of how the 35 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 applicable regulatory authority, 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 conditions.

( 3) Upon receipt, the regulatory authority 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 ( f)( 2) of this section; and ( ii) Whether the plan presents sufficient information 36 to determine that compliance will be achieved and maintained.

( 4) The applicable regulatory authority 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 large solid fuel boiler, except for a new gaseous fuel boiler that replaces an existing large solid fuel boiler.

§ 63.7525 What are my monitoring, installation, operation,

and maintenance requirements?

( a) If you have an applicable work practice standard for carbon monoxide, and your boiler or process heater has a heat input capacity of 100 million Btu per hour or greater,

you must install, operate, and maintain a continuous emission monitoring system ( CEMS) for carbon monoxide according to the procedures in paragraphs ( a)( 1) through ( 5)

of this section by the compliance date specified in § 63.7495.

( 1) Each CEMS must be installed, operated, and maintained according to Performance Specification ( PS) 4A of 40 CFR part 60, appendix B, and according to the sitespecific monitoring plan developed according to § 63.7505( d). 37 ( 2) You must conduct a performance evaluation of each CEMS according to the requirements in § 63.8 and according to PS 4A of 40 CFR part 60, appendix B.

( 3) Each CEMS must complete a minimum of one cycle of operation ( sampling, analyzing, and data recording) for each successive 15 minute period.

( 4) The CEMS data must be reduced as specified in § 63.8( g)( 2).

( 5) For purposes of calculating data averages, you must not use data recorded during periods of monitoring malfunctions, associated repairs, out of control periods,

required quality assurance or control activities, or when your boiler or process heater is operating at less than 50 percent of its rated capacity. You must use all the data collected during all other periods in assessing compliance.

Any period for which the monitoring system is out of control and data are not available for required calculations constitutes a deviation from the monitoring requirements.

( b) If you have an applicable opacity operating limit,

you must install, operate, certify and maintain each continuous opacity monitoring system ( COMS) according to the procedures in paragraphs ( b)( 1) through ( 7) of this section by the compliance date specified in § 63.7495.

( 1) Each COMS must be installed, operated, and maintained according to PS 1 of 40 CFR part 60, appendix B. 38 ( 2) You must conduct a performance evaluation of each COMS according to the requirements in § 63.8 and according to PS 1 of 40 CFR part 60, appendix B.

( 3) As specified in § 63.8( c)( 4)( i), 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.

( 4) The COMS data must be reduced as specified in § 63.8( g)( 2).

( 5) You must include in your site specific monitoring plan procedures and acceptance criteria for operating and maintaining each COMS according to the requirements in § 63.8( d). At a minimum, the monitoring plan must include a daily calibration drift assessment, a quarterly performance audit, and an annual zero alignment audit of each COMS.

( 6) You must operate and maintain each COMS according to the requirements in the monitoring plan and the requirements of § 63.8( e). Identify periods the COMS is out of control including any periods that the COMS fails to pass a daily calibration drift assessment, a quarterly performance audit, or an annual zero alignment audit.

( 7) You must determine and record all the 6 minute averages ( and 1 hour block averages as applicable) collected for periods during which the COMS is not out of control.

( c) If you have an operating limit that requires the 39 use of a continuous monitoring system, you must install,

operate, and maintain each continuous parameter monitoring system ( CPMS) according to the procedures in paragraphs ( c)( 1) through ( 5) of this section by the compliance date specified in § 63.7495.

( 1) The CPMS must complete a minimum of one cycle of operation for each successive 15 minute period. You must have a minimum of four successive cycles of operation to have a valid hour of data.

( 2) Except for monitoring malfunctions, associated repairs, and required quality assurance or control activities ( including, as applicable, calibration checks and required zero and span adjustments), you must conduct all monitoring in continuous operation at all times that the unit is operating. A monitoring malfunction is any sudden,

infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions.

( 3) For purposes of calculating data averages, you must not use data recorded during monitoring malfunctions,

associated repairs, out of control periods, or required quality assurance or control activities. You must use all the data collected during all other periods in assessing compliance. Any period for which the monitoring system is 40 out of control and data are not available for required calculations constitutes a deviation from the monitoring requirements.

( 4) Determine the 3 hour block average of all recorded readings, except as provided in paragraph ( c)( 3) of this section.

( 5) Record the results of each inspection,

calibration, and validation check.

( d) If you have an operating limit that requires the use of a flow measurement device, you must meet the requirements in paragraphs ( c) and ( d)( 1) through ( 4) of this section.

( 1) Locate the flow sensor and other necessary equipment in a position that provides a representative flow.

( 2) Use a flow sensor with a measurement sensitivity of 2 percent of the flow rate.

( 3) Reduce swirling flow or abnormal velocity distributions due to upstream and downstream disturbances.

( 4) Conduct a flow sensor calibration check at least semiannually.

( e) If you have an operating limit that requires the use of a pressure measurement device, you must meet the requirements in paragraphs ( c) and ( e)( 1) through ( 6) of this section.

( 1) Locate the pressure sensor( s) in a position that 41 provides a representative measurement of the pressure.

( 2) Minimize or eliminate pulsating pressure,

vibration, and internal and external corrosion.

( 3) Use a gauge with a minimum tolerance of 1.27 centimeters of water or a transducer with a minimum tolerance of 1 percent of the pressure range.

( 4) Check pressure tap pluggage daily.

( 5) Using a manometer, check gauge calibration quarterly and transducer calibration monthly.

( 6) Conduct calibration checks any time the sensor exceeds the manufacturer's specified maximum operating pressure range or install a new pressure sensor.

( f) If you have an operating limit that requires the use of a pH measurement device, you must meet the requirements in paragraphs ( c) and ( f)( 1) through ( 3) of this section.

( 1) Locate the pH sensor in a position that provides a representative measurement of scrubber effluent pH.

( 2) Ensure the sample is properly mixed and representative of the fluid to be measured.

( 3) Check the pH meter's calibration on at least two points every 8 hours of process operation.

( g) If you have an operating limit that requires the use of equipment to monitor voltage and secondary current ( or total power input) of an electrostatic precipitator 42 ( ESP), you must use voltage and secondary current monitoring equipment to measure voltage and secondary current to the ESP.

( h) If you have an operating limit that requires the use of equipment to monitor sorbent injection rate ( e. g.,

weigh belt, weigh hopper, or hopper flow measurement device), you must meet the requirements in paragraphs ( c)

and ( h)( 1) through ( 3) of this section.

( 1) Locate the device in a position( s) that provides a representative measurement of the total sorbent injection rate.

( 2) Install and calibrate the device in accordance with manufacturer's procedures and specifications.

( 3) At least annually, calibrate the device in accordance with the manufacturer's procedures and specifications.

( i) If you elect to use a fabric filter bag leak detection system to comply with the requirements of this subpart, you must install, calibrate, maintain, and continuously operate a bag leak detection system as specified in paragraphs ( i)( 1) through ( 8) of this section.

( 1) You must install and operate a bag leak detection system for each exhaust stack of the fabric filter.

( 2) Each bag leak detection system must be installed,

operated, calibrated, and maintained in a manner consistent 43 with the manufacturer's written specifications and recommendations and in accordance with the guidance provided in EPA 454/ R 98 015, September 1997.

( 3) The bag leak detection system must be certified by the manufacturer to be capable of detecting particulate matter emissions at concentrations of 10 milligrams per actual cubic meter or less.

( 4) The bag leak detection system sensor must provide output of relative or absolute particulate matter loadings.

( 5) The bag leak detection system must be equipped with a device to continuously record the output signal from the sensor.

( 6) The bag leak detection system must be equipped with an alarm system that will sound automatically when an increase in relative particulate matter emissions over a preset level is detected. The alarm must be located where it is easily heard by plant operating personnel.

( 7) For positive pressure fabric filter systems that do not duct all compartments of cells to a common stack, a bag leak detection system must be installed in each baghouse compartment or cell.

( 8) Where multiple bag leak detectors are required,

the system's instrumentation and alarm may be shared among detectors.

§ 63.7530 How do I demonstrate initial compliance with the 44 emission limits and work practice standards?

( a) You must demonstrate initial compliance with each emission limit and work practice standard that applies to you by either conducting initial performance tests and establishing operating limits, as applicable, according to § 63.7520, paragraph ( c) of this section, and Tables 5 and 7 to this subpart OR conducting initial fuel analyses to determine emission rates and establishing operating limits,

as applicable, according to § 63.7521, paragraph ( d) of this section, and Tables 6 and 7 to this subpart.

( b) New or reconstructed boilers or process heaters in one of the liquid fuel subcategories that burn only fossil fuels and other gases and do not burn any residual oil must demonstrate compliance according to § 63.7506( a).

( c) If you demonstrate compliance through performance testing, you must establish each site specific operating limit in Tables 2 through 4 to this subpart that applies to you according to the requirements in § 63.7520, Table 7 to this subpart, and paragraph ( c) ( 4) of this section, as applicable. You must also conduct fuel analyses according to § 63.7521 and establish maximum fuel pollutant input operating limits according to paragraphs ( c)( 1) through ( 3)

of this section, as applicable.

( 1) You must establish a chlorine fuel input operating limit based on the maximum chlorine fuel input ( Clinput) 45 established during the initial performance testing according to the procedures in paragraphs ( c)( 1)( i) through ( iii) of this section.

( i) You must determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of chlorine.

( ii) During the performance testing for HCl, you must determine the fraction of the total heat input for each fuel type burned ( Qi) based on the fuel mixture that has the highest content of chlorine, and the average chlorine concentration of each fuel type burned ( Ci).

( iii) You must establish a maximum chlorine input level using Equation 1 of this section.

( Eq. 2) [ ] C CQ input i n i i 1 1 = =  ( )( )

Where:

Clinput = Maximum amount of chlorine entering the boiler or process heater through fuels burned in units of pounds per million Btu. This is your operating limit for chlorine fuel input. Ci = Arithmetic average concentration of chlorine in fuel type, i, analyzed according to § 63.7521, in units of pounds per million Btu Qi = Fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of chlorine. If you do not burn multiple fuel types during the performance testing, it is not necessary to determine the value of this term. Insert a value of " 1" for . Qi 46 n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of chlorine.

( 2) If you choose to comply with the alternative TSM emission limit instead of the particulate matter emission limit, you must establish a TSM fuel input operating limit based on the maximum TSM fuel input ( Metalsinput)

established during the initial performance testing according to the procedures in paragraphs ( c)( 2)( i) through ( iii) of this section.

( i) You must determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of TSM.

( ii) During the performance testing for TSM, you must determine the fraction of total heat input from each fuel burned ( Qi) based on the fuel mixture that has the highest content of total selected metals, and the average TSM concentration of each fuel type burned ( Mi).

( ii) You must establish a baseline TSM input level using Equation 2 of this section.

( Eq. 2) [ ] Metals M Q input i n i i = =  1 ( )( )

Where:

Metalsinput = Maximum amount of TSM entering the boiler or process heater through fuels burned in units of pounds per million Btu. This is your operating limit for TSM fuel input. 47 Mi = Arithmetic average concentration of TSM in fuel type, i, analyzed according to § 63.7521, in units of pound per million Btu Qi = Fraction of total heat input from based fuel type, i, based on the fuel mixture that has the highest content of TSM. If you do not burn multiple fuel types during the performance test, it is not necessary to determine the value of this term. Insert a value of " 1" for Qi. n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of TSM.

( 3) You must establish a mercury fuel input operating limit based on the maximum mercury fuel input ( Mercuryinput)

established during the initial performance testing using the procedures in paragraphs ( c)( 3)( i) through ( iii) of this section.

( i) You must determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of mercury.

( ii) During the compliance demonstration for mercury,

you must determine the fraction of total heat input for each fuel burned ( Qi) based on the fuel mixture that has the highest content of mercury, and the average mercury concentration of each fuel type burned ( HGi).

( iii) You must establish a maximum mercury input level using Equation 3 of this section. 48 ( Eq. 3) [ ] Mercury HG Q input i n i i = =

1 ( )( )

Where:

Mercuryinput = Maximum amount of mercury entering the boiler or process heater through fuels burned in units of pounds per million Btu. This is your operating limit for mercury fuel input. HGi = Arithmetic average concentration of mercury in fuel type, i, analyzed according to § 63.7521, in units of pound per million Btu . Qi = Fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest mercury content. If you do not burn multiple fuel types during the performance test, it is not necessary to determine the value of this term. Insert a value of " 1" for Qi. n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of mercury.

( 4) You must establish parameter operating limits according to paragraphs ( c)( 4)( i) through ( iv) of this section.

( i) For a wet scrubber, you must establish the minimum scrubber effluent pH, liquid flowrate, and pressure drop as defined in § 63.7575, as your operating limits during the three run performance test. If you use a wet scrubber and you conduct separate performance tests for particulate matter, HCl, and mercury emissions, you must establish one set of minimum scrubber effluent pH, liquid flowrate, and pressure drop operating limits. The minimum scrubber 49 effluent pH operating limit must be established during the HCl performance test. If you conduct multiple performance tests, you must set the minimum liquid flowrate and pressure drop operating limits at the highest minimum values established during the performance tests.

( ii) For an electrostatic precipitator, you must establish the minimum voltage and secondary current ( or total power input), as defined in § 63.7575, as your operating limits during the three run performance test.

( iii) For a dry scrubber, you must establish the minimum sorbent injection rate, as defined in § 63.7575, as your operating limit during the three run performance test.

( iv) The operating limit for boilers or process heaters with fabric filters that choose to demonstrate continuous compliance through bag leak detection systems is that a bag leak detection system be installed according to the requirements in § 63.7525, and that each fabric filter must be operated such that the bag leak detection system alarm does not sound more than 5 percent of the operating time during a 6 month period.

( d) If you elect to demonstrate compliance with an applicable emission limit through fuel analysis, you must conduct fuel analyses according to § 63.7521 and follow the procedures in paragraphs ( d)( 1) through ( 5) of this section.

( 1) If you burn more than one fuel type, you must 50 determine the fuel mixture you could burn in your boiler or process heater that would result in the highest emission rates of the pollutants that you elect to demonstrate compliance through fuel analysis. The emission rates calculated according to paragraphs ( d)( 3) through ( 5) of this section are your operating limits.

( 2) You must determine the 90th percentile confidence level fuel pollutant concentration of the composite samples analyzed for each fuel type using the one sided z statistic test described in Equation 4 of this section.

P90 = mean + ( SD * t) ( Eq. 4)

Where:

P90 = 90th percentile confidence level pollutant concentration, in pounds per million Btu. mean = Arithmetic average of the fuel pollutant concentration in the fuel samples analyzed according to § 63.7521, in units of pounds per million Btu. SD = Standard deviation of the pollutant concentration in the fuel samples analyzed according to § 63.7521, in units of pounds per million Btu. t = t distribution critical value for 90th percentile ( 0.1) probability for the appropriate degrees of freedom ( number of samples minus one) as obtained from a Distribution Critical Value Table.

( 3) To demonstrate compliance with the applicable emission limit for HCl, the HCl emission rate that you calculate for your boiler or process heater using Equation 5 of this section must be less than the applicable emission limit for HCl. 51 ( Eq. 5) [ ] HCl C Q i i i n =

=  ( )( )(. ) 90 1 1028 Where:

HCl = HCl emission rate from the boiler or process heater in units of pounds per million Btu. This is your operating limit. Ci90 = 90th percentile confidence level concentration of chlorine in fuel type, i, in units of pounds per million Btu as calculated according to Equation 4 of this section Qi = Fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of chlorine. If you do not burn multiple fuel types, it is not necessary to determine the value of this term. Insert a value of " 1" for Qi n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of chlorine . 1.028= Molecular weight ratio of HCl to chlorine.

( 4) To demonstrate compliance with the applicable emission limit for TSM, the TSM emission rate that you calculate for your boiler or process heater using Equation 6 of this section must be less than the applicable emission limit for TSM.

( Eq. 6) [ ] Metals M Q i i i n = =

( )( ) 90 1 Where:

Metals = TSM emission rate from the boiler or process heater in units of pounds per million Btu. This is your operating limit. Mi90 = 90th percentile confidence level concentration of TSM in fuel, i, in units of pound per million Btu as calculated according to Equation 4 of this section Qi = Fraction of total heat input from fuel 52 type, i, based on the fuel mixture that has the highest content of total selected metals. If you do not burn multiple fuel types, it is not necessary to determine the value of this term. Insert a value of " 1" for Qi. n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of TSM.

( 5) To demonstrate compliance with the applicable emission limit for mercury, the mercury emission rate that you calculate for your boiler or process heater using Equation 7 of this section must be less than the applicable emission limit for mercury.

( Eq. 7) [ ] Mercury HG Q i i i n = =

( )( ) 90 1 Where:

Mercury = Mercury emission rate from the boiler or process heater in units of pounds per million Btu. This is your operating limit. HGi90 = 90th percentile confidence level concentration of mercury in fuel, i, in units of pound per million Btu as calculated according to Equation 4 of this section. Qi = Fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest mercury content. If you do not burn multiple fuel types , it is not necessary to determine the value of this term. Insert a value of " 1" for Qi. n = Number of different fuel types burned in your boiler or process heater for the mixture that has the highest mercury content. 53 ( e) You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in § 63.7545( e).

Continuous Compliance Requirements § 63.7535 How do I monitor and collect data to demonstrate continuous compliance?

( a) You must monitor and collect data according to this section and the site specific monitoring plan required by § 63.7505( d).

( b) 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 that the affected source is operating.

( c) You may not use data recorded during monitoring malfunctions, associated repairs, or required quality assurance or control activities in data averages and calculations used to report emission or operating levels.

You must use all the data collected during all other periods in assessing the operation of the control device and associated control system. Boilers and process heaters that have an applicable carbon monoxide work practice standard and are required to install and operate a CEMS, may not use data recorded during periods when the boiler or process 54 heater is operating at less than 50 percent of its rated capacity.

§ 63.7540 How do I demonstrate continuous compliance with the emission limits and work practice standards?

( a) You must demonstrate continuous compliance with each emission limit, operating limit, and work practice standard in Tables 1 through 4 to this subpart that applies to you according to the methods specified in Table 8 to this subpart and paragraphs ( a)( 1) through ( 11) of this section.

( 1) Following the date on which the initial performance test is completed or is required to be completed under § § 63.7 and 63.7510, whichever date comes first, you must not operate above any of the applicable maximum operating limits or below any of the applicable minimum operating limits listed in Tables 2 through 4 to this subpart at all times except during periods of startup,

shutdown and malfunction. Operating limits do not apply during performance tests. Operation above the established maximum or below the established minimum operating limits shall constitute a deviation of established operating limits.

( 2) You must keep records of the type and amount of all fuels burned in each boiler or process heater during the reporting period to demonstrate that all fuel types and mixtures of fuels burned would either result in lower 55 emissions of TSM, HCl, and mercury, than the applicable emission limit for each pollutant ( if you demonstrate compliance through fuel analysis), or result in lower fuel input of TSM, chlorine, and mercury than the maximum values calculated during the last performance tests ( if you demonstrate compliance through performance testing).

( 3) If you demonstrate compliance with an applicable HCl emission limit through fuel analysis and you plan to burn a new type of fuel, you must recalculate the HCl emission rate using Equation 5 of § 63.7530 according to paragraphs ( a)( 3)( i) through ( iii) of this section.

( i) You must determine the chlorine concentration for any new fuel type in units of pounds per million Btu, based on supplier data or your own fuel analysis, according to the provisions in your site specific fuel analysis plan developed according to § 63.7521( b).

( ii) You must determine the new mixture of fuels that will have the highest content of chlorine.

( iii) Recalculate the HCl emission rate from your boiler or process heater under these new conditions using Equation 5 of § 63.7530. The recalculated HCl emission rate must be less than the applicable emission limit.

( 4) If you demonstrate compliance with an applicable HCl emission limit through performance testing and you plan to burn a new type of fuel type or a new mixture of fuels, 56 you must recalculate the maximum chlorine input using Equation 1 of § 63.7530. If the results of recalculating the maximum chlorine input using Equation 1 of § 63.7530 are higher than the maximum chlorine input level established during the previous performance test, then you must conduct a new performance test within 60 days of burning the new fuel type or fuel mixture according to the procedures in § 63.7520 to demonstrate that the HCl emissions do not exceed the emission limit. You must also establish new operating limits based on this performance test according to the procedures in § 63.7530( c).

( 5) If you demonstrate compliance with an applicable total selected metals emission limit through fuel analysis,

and you plan to burn a new type of fuel, you must recalculate the total selected metals emission rate using Equation 6 of § 63.7530 according to the procedures specified in paragraphs ( a)( 5)( i) through ( iii) of this section.

( i) You must determine the TSM concentration for any new fuel type in units of pounds per million Btu, based on supplier data or your own fuel analysis, according to the provisions in your site specific fuel analysis plan developed according to § 63.7521( b).

( ii) You must determine the new mixture of fuels that will have the highest content of TSM.

( iii) Recalculate the TSM emission rate from your 57 boiler or process heater under these new conditions using Equation 6 of § 63.7530. The recalculated TSM emission rate must be less than the applicable emission limit.

( 6) If you demonstrate compliance with an applicable TSM emission limit through performance testing, and you plan to burn a new type of fuel or a new mixture of fuels, you must recalculate the maximum TSM input using Equation 2 of § 63.7530. If the results of recalculating the maximum total selected metals input using Equation 2 of § 63.7530 are higher than the maximum TSM input level established during the previous performance test, then you must conduct a new performance test within 60 days of burning the new fuel type or fuel mixture according to the procedures in § 63.7520 to demonstrate that the TSM emissions do not exceed the emission limit. You must also establish new operating limits based on this performance test according to the procedures in § 63.7530( c).

( 7) If you demonstrate compliance with an applicable mercury emission limit through fuel analysis, and you plan to burn a new type of fuel, you must recalculate the mercury emission rate using Equation 7 of § 63.7530 according to the procedures specified in paragraphs ( a)( 7)( i) through ( iii)

of this section.

( i) You must determine the mercury concentration for any new fuel type in units of pounds per million Btu, based 58 on supplier data or your own fuel analysis, according to the provisions in your site specific fuel analysis plan developed according to § 63.7521( b).

( ii) You must determine the new mixture of fuels that will have the highest content of mercury.

( iii) Recalculate the mercury emission rate from your boiler or process heater under these new conditions using Equation 7 of § 63.7530. The recalculated mercury emission rate must be less than the applicable emission limit.

( 8) If you demonstrate compliance with an applicable mercury emission limit through performance testing, and you plan to burn a new type of fuel or a new mixture of fuels,

you must recalculate the maximum mercury input using Equation 3 of § 63.7530. If the results of recalculating the maximum mercury input using Equation 3 of § 63.7530 are higher than the maximum mercury input level established during the previous performance test, then you must conduct a new performance test within 60 days of burning the new fuel type or fuel mixture according to the procedures in § 63.7520 to demonstrate that the mercury emissions do not exceed the emission limit. You must also establish new operating limits based on this performance test according to the procedures in § 63.7530( c).

( 9) If your unit is controlled with a fabric filter,

and you demonstrate continuous compliance using a bag leak 59 detection system, you must operate each fabric filter system such that the bag leak detection system does not sound more than 5 percent of the operating time during a 6 month period. You must also keep records of the date, time, and duration of each alarm, the time corrective action was initiated and completed, and a brief description of the cause of the alarm and the corrective action taken. You must also record the percent of the operating time during each 6 month period that the alarm sounds. In calculating this operating time percentage, if inspection of the fabric filter demonstrates that no corrective action is required,

no alarm time is counted. If corrective action is required,

each alarm shall be counted as a minimum of 1 hour. If you take longer than 1 hour to initiate corrective action, the alarm time shall be counted as the actual amount of time taken to initiate corrective action.

( 10) If you have an applicable work practice standard for carbon monoxide, and you are required to install a CEMS according to § 63.7525( a), then you must meet the requirements in paragraphs ( a)( 10)( i) through ( iii) of this section.

( i) You must continuously monitor carbon monoxide according to § § 63.7525( a) and 63.7535.

( ii) Maintain a carbon monoxide emission level below your applicable carbon monoxide work practice standard in 60 Table 1 to this subpart at all times except during periods of startup, shutdown, malfunction, and when your boiler or process heater is operating at less than 50 percent of rated capacity.

( iii) Keep records of carbon monoxide levels according to § 63.7555( b).

( b) You must report each instance in which you did not meet each emission limit, operating limit, and work practice standard in Tables 1 through 4 to this subpart that apply to you. You must also report each instance during a startup,

shutdown, or malfunction when you did not meet each applicable emission limit, operating limit, and work practice standard. These instances are deviations from the emission limits and work practice standards in this subpart.

These deviations must be reported according to the requirements in § 63.7550.

( c) During periods of startup, shutdown, and malfunction, you must operate in accordance with the SSMP as required in § 63.7505( e).

( d) Consistent with § § 63.6( e) and 63.7( e)( 1),

deviations that occur during a period of startup, shutdown,

or malfunction are not violations if you demonstrate to the EPA Administrator's satisfaction that you were operating in accordance with your SSMP. The EPA Administrator will determine whether deviations that occur during a period of 61 startup, shutdown, or malfunction are violations, according to the provisions in § 63.6( e).

§ 63.7541 How do I demonstrate continuous compliance under the emission averaging provision?

( a) Following the compliance date, the owner or operator must demonstrate compliance with this subpart on a continuous basis by meeting the requirements of paragraphs ( a)( 1) through ( 4) of this section.

( 1) For each calendar month, demonstrate compliance with the average weighted emissions limit for the existing large solid fuel boilers participating in the emissions averaging option as determined in § 63.7522( f) and ( g);

( 2) For each existing solid fuel boiler participating in the emissions averaging option that is equipped with a dry control system, maintain opacity at or below the applicable limit;

( 3) For each existing solid fuel boiler participating in the emissions averaging option that is equipped with a wet scrubber, maintain the 3 hour average parameter values at or below the operating limits established during the most recent performance test; and ( 4) For each existing solid fuel boiler participating in the emissions averaging option that has an approved alternative operating plan, maintain the 3 hour average parameter values at or below the operating limits 62 established in the most recent performance test.

( b) Any instance where the owner or operator fails to comply with the continuous monitoring requirements in paragraphs ( a)( 1) through ( 4) of this section, except during periods of startup, shutdown, and malfunction, is a deviation.

Notification, Reports, and Records § 63.7545 What notifications must I submit and when?

( a) You must submit all of the notifications in § § 63.7( b) and ( c), 63.8 ( e), ( f)( 4) and ( 6), and 63.9 ( b)

through ( h) that apply to you by the dates specified.

( b) As specified in § 63.9( b)( 2), if you startup your affected source before [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must submit an Initial Notification not later than 120 calendar days after [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER]. The Initial Notification must include the information required in paragraphs ( b)( 1) and ( 2) of this section, as applicable.

( 1) If your affected source has an annual capacity factor of greater than 10 percent, your Initial Notification must include the information required by § 63.9( b)( 2).

( 2) If your affected source has a federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent such that the unit is in 63 one of the limited use subcategories ( the limited use solid fuel subcategory, the limited use liquid fuel subcategory,

or the limited use gaseous fuel subcategory), your Initial Notification must include the information required by § 63.9( b)( 2) and also a signed statement indicating your affected source has a federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent.

( c) As specified in § 63.9( b)( 3), if you startup your new or reconstructed affected source on or after [ INSERT THE DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must submit an Initial Notification not later than 120 calendar days after you become subject to this subpart. The Initial Notification must include the information required in paragraphs ( c)( 1) and ( 2) of this section, as applicable.

( 1) If your affected source has an annual capacity factor of greater than 10 percent, your Initial Notification must include the information required by § 63.9( b).

( 2) If your affected source has a federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent such that the unit is in one of the limited use subcategories, your Initial Notification must include the information required by § 63.9( b) and a signed statement indicating your affected 64 source has a federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent.

( d) If you are required to conduct a performance test you must submit a Notification of Intent to conduct a performance test at least 30 calendar days before the performance test is scheduled to begin as required in § 63.7( b)( 1).

( e) If you are required to conduct an initial compliance demonstration as specified in § 63.7530( a), you must submit a Notification of Compliance Status according to § 63.9( h)( 2)( ii). For each initial compliance demonstration,

you must submit the Notification of Compliance Status,

including all performance test results and fuel analyses,

before the close of business on the 60th calendar day following the completion of the performance test and/ or other initial compliance demonstrations according to § 63.10( d)( 2). The Notification of Compliance Status report must contain all the information specified in paragraphs ( e)( l) through ( 9), as applicable.

( 1) A description of the affected source( s) including identification of which subcategory the source is in, the capacity of the source, a description of the add on controls used on the source description of the fuel( s) burned, and justification for the fuel( s) burned during the performance test. 65 ( 2) Summary of the results of all performance tests,

fuel analyses, and calculations conducted to demonstrate initial compliance including all established operating limits.

( 3) Identification of whether you are complying with the particulate matter emission limit or the alternative total selected metals emission limit.

( 4) Identification of whether you plan to demonstrate compliance with each applicable emission limit through performance testing or fuel analysis.

( 5) Identification of whether you plan to demonstrate compliance by emissions averaging.

( 6) A signed certification that you have met all applicable emission limits and work practice standards.

( 7) A summary of the carbon monoxide emissions monitoring data and the maximum carbon monoxide emission levels recorded during the performance test to show that you have met any applicable work practice standard in Table 1 to this subpart.

( 8) If your new or reconstructed boiler or process heater is in one of the liquid fuel subcategories and burns only liquid fossil fuels other than residual oil either alone or in combination with gaseous fuels, you must submit a signed statement certifying this in your Notification of Compliance Status report. 66 ( 9) If you had a deviation from any emission limit or work practice standard, you must also submit a description of the deviation, the duration of the deviation, and the corrective action taken in the Notification of Compliance Status report.

§ 63.7550 What reports must I submit and when?

( a) You must submit each report in Table 9 to this subpart that applies to you.

( b) Unless the EPA Administrator has approved a different schedule for submission of reports under § 63.10( a), you must submit each report by the date in Table 9 to this subpart and according to the requirements in paragraphs ( b)( 1) through ( 5) of this section.

( 1) The first compliance report must cover the period beginning on the compliance date that is specified for your affected source in § 63.7495 and ending on June 30 or December 31, whichever date is the first date that occurs at least 180 days after the compliance date that is specified for your source in § 63.7495.

( 2) The first compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for your source in § 63.7495.

( 3) Each subsequent compliance report must cover the 67 semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31.

( 4) Each subsequent compliance report 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.

( 5) 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 § 70.6( a)( 3)( iii)( A) or § 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 ( b)( 1) through ( 4) of this section.

( c) The compliance report must contain the information required in paragraphs ( c)( 1) through ( 11) of this section.

( 1) Company name and address.

( 2) Statement by a responsible official with that official's name, title, and signature, certifying the truth,

accuracy, and completeness of the content of the report.

( 3) Date of report and beginning and ending dates of the reporting period.

( 4) The total fuel use by each affected source subject 68 to an emission limit, for each calendar month within the semiannual reporting period, including, but not limited to,

a description of the fuel and the total fuel usage amount with units of measure.

( 5) A summary of the results of the annual performance tests and documentation of any operating limits that were reestablished during this test, if applicable.

( 6) A signed statement indicating that you burned no new types of fuel. Or, if you did burn a new type of fuel,

you must submit the calculation of chlorine input, using Equation 1 of § 63.7530, that demonstrates that your source is still within its maximum chlorine input level established during the previous performance testing ( for sources that demonstrate compliance through performance testing) or you must submit the calculation of HCl emission rate using Equation 5 of § 63.7530 that demonstrates that your source is still meeting the emission limit for HCl emissions ( for boilers or process heaters that demonstrate compliance through fuel analysis). If you burned a new type of fuel,

you must submit the calculation of total selected metals input, using Equation 2 of § 63.7530, that demonstrates that your source is still within its maximum total selected metals input level established during the previous performance testing ( for sources that demonstrate compliance through performance testing), or you must submit the 69 calculation of total selected metals emission rate using Equation 6 of § 63.7530 that demonstrates that your source is still meeting the emission limit for total selected metals emissions ( for boilers or process heaters that demonstrate compliance through fuel analysis). If you burned a new type of fuel, you must submit the calculation of mercury input,

using Equation 3 of § 63.7530, that demonstrates that your source is still within its maximum mercury input level established during the previous performance testing ( for sources that demonstrate compliance through performance testing), or you must submit the calculation of mercury emission rate using Equation 7 of § 63.7530 that demonstrates that your source is still meeting the emission limit for mercury emissions ( for boilers or process heaters that demonstrate compliance through fuel analysis).

( 7) If you wish to burn a new type of fuel and you can not demonstrate compliance with the maximum chlorine input operating limit using Equation 1 of § 63.7530, the maximum total selected metals input operating limit using Equation 2 of § 63.7530, or the maximum mercury input operating limit using Equation 3 of § 63.7530, you must include in the compliance report a statement indicating the intent to conduct a new performance test within 60 days of starting to burn the new fuel.

( 8) The hours of operation for each boiler and process 70 heater that is subject to an emission limit for each calendar month within the semiannual reporting period. This requirement applies only to limited use boilers and process heaters.

( 9) If you had a startup, shutdown, or malfunction during the reporting period and you took actions consistent with your SSMP, the compliance report must include the information in § 63.10( d)( 5)( i).

( 10) If there are no deviations from any emission limits or operating limits in this subpart that apply to you, and there are no deviations from the requirements for work practice standards in this subpart, a statement that there were no deviations from the emission limits, operating limits, or work practice standards during the reporting period.

( 11) If there were no periods during which the continuous monitoring systems, including CEMS, COMS, and CPMS, were out of control as specified in § 63.8( c)( 7), a statement that there were no periods during which the continuous monitoring systems were out of control during the reporting period.

( d) For each deviation from an emission limit or operating limit in this subpart 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 71 continuous monitoring systems to comply with that emission limit, operating limit, or work practice standard, the compliance report must contain the information in paragraphs ( c)( 1) through ( 10) of this section and the information required in paragraphs ( d)( 1) through ( 4) of this section.

This includes periods of startup, shutdown, and malfunction.

( 1) The total operating time of each affected source during the reporting period.

( 2) A description of the deviation and which emission limit, operating limit, or work practice standard from which you deviated.

( 3) Information on the number, duration, and cause of deviations ( including unknown cause), as applicable, and the corrective action taken.

( 4) A copy of the test report if the annual performance test showed a deviation from the emission limit for particulate matter or the alternative TSM limit, a deviation from the HCl emission limit, or a deviation from the mercury emission limit.

( e) For each deviation from an emission limitation and operating limit or work practice standard in this subpart occurring at an affected source where you are using a continuous monitoring system to comply with that emission limit, operating limit, or work practice standard, you must include the information in paragraphs ( c)( 1) through ( 10) of 72 this section and the information required in paragraphs ( e)( 1) through ( 12) of this section. This includes periods of startup, shutdown, and malfunction and any deviations from your site specific monitoring plan as required in § 63.7505( d).

( 1) The date and time that each malfunction started and stopped and description of the nature of the deviation ( i. e., what you deviated from).

( 2) The date and time that each continuous monitoring system was inoperative, except for zero ( low level) and high level checks.

( 3) The date, time, and duration that each continuous monitoring system was out of control, including the information in § 63.8( c)( 8).

( 4) The date and time that each deviation started and stopped, and whether each deviation occurred during a period of startup, shutdown, or malfunction or during another period.

( 5) A summary of the total duration of the deviation during the reporting period and the total duration as a percent of the total source operating time during that reporting period.

( 6) A breakdown of the total duration of the deviations during the reporting period into those that are due to startup, shutdown, control equipment problems, 73 process problems, other known causes, and other unknown causes.

( 7) A summary of the total duration of continuous monitoring systems downtime during the reporting period and the total duration of continuous monitoring system downtime as a percent of the total source operating time during that reporting period.

( 8) An identification of each parameter that was monitored at the affected source for which there was a deviation, including opacity, carbon monoxide, and operating parameters for wet scrubbers and other control devices.

( 9) A brief description of the source for which there was a deviation.

( 10) A brief description of each continuous monitoring system for which there was a deviation.

( 11) The date of the latest continuous monitoring system certification or audit for the system for which there was a deviation.

( 12) A description of any changes in continuous monitoring systems, processes, or controls since the last reporting period for the source for which there was a deviation.

( f) Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 40 CFR part 71 must report all deviations as defined in this subpart in 74 the semiannual monitoring report required by § 70.6( a)( 3)( iii)( A) or § 71.6( a)( 3)( iii)( A). If an affected source submits a compliance report pursuant to Table 9 to this subpart along with, or as part of, the semiannual monitoring report required by § 70.6( a)( 3)( iii)( A) or § 71.6( a)( 3)( iii)( A), and the compliance report includes all required information concerning deviations from any emission limit operating limit, or work practice requirement 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 the affected source may have to report deviations from permit requirements to the permit authority.

( g) If you operate a new gaseous fuel unit that is subject to the work practice standard specified in Table 1 to this subpart, and you intend to use a fuel other than natural gas or equivalent to fire the affected unit, you must submit a notification of alternative fuel use within 48 hours of the declaration of a period of natural gas curtailment or supply interruption, as defined in § 63.7575.

The notification must include the information specified in paragraphs ( g)( 1) through ( 5) of this section.

( 1) Company name and address.

( 2) Identification of the affected unit. 75 ( 3) Reason you are unable to use natural gas or equivalent fuel, including the date when the natural gas curtailment was declared or the natural gas supply interruption began.

( 4) Type of alternative fuel that you intend to use.

( 5) Dates when the alternative fuel use is expected to begin and end.

§ 63.7555 What records must I keep?

( a) You must keep records according to paragraphs ( a)( 1) through ( 3) 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 or semiannual compliance report that you submitted, according to the requirements in § 63.10( b)( 2)( xiv).

( 2) The records in § 63.6( e)( 3)( iii) through ( v)

related to startup, shutdown, and malfunction.

( 3) Records of performance tests, fuel analyses, or other compliance demonstrations, performance evaluations,

and opacity observations as required in § 63.10( b)( 2)( viii).

( b) For each CEMS, CPMS, and COMS, you must keep records according to paragraphs ( b)( 1) through ( 5) of this section.

( 1) Records described in § 63.10( b)( 2)( vi) through 76 ( xi).

( 2) Monitoring data for continuous opacity monitoring system during a performance evaluation as required in § 63.6( h)( 7)( i) and ( ii).

( 3) Previous ( i. e., superseded) versions of the performance evaluation plan as required in § 63.8( d)( 3).

( 4) Request for alternatives to relative accuracy test for CEMS as required in § 63.8( f)( 6)( i).

( 5) Records of the date and time that each deviation started and stopped, and whether the deviation occurred during a period of startup, shutdown, or malfunction or during another period.

( c) You must keep the records required in Table 8 to this subpart including records of all monitoring data and calculated averages for applicable operating limits such as opacity, pressure drop, carbon monoxide, and pH to show continuous compliance with each emission limit, operating limit, and work practice standard that applies to you.

( d) For each boiler or process heater subject to an emission limit, you must also keep the records in paragraphs ( d)( 1) through ( 5) of this section.

( 1) You must keep records of monthly fuel use by each boiler or process heater, including the type( s) of fuel and amount( s) used.

( 2) You must keep records of monthly hours of 77 operation by each boiler or process heater. This requirement applies only to limited use boilers and process heaters.

( 3) A copy of all calculations and supporting documentation of maximum chlorine fuel input, using Equation 1 of § 63.7530, that were done to demonstrate continuous compliance with the HCl emission limit, for sources that demonstrate compliance through performance testing. For sources that demonstrate compliance through fuel analysis, a copy of all calculations and supporting documentation of HCl emission rates, using Equation 5 of § 63.7530, that were done to demonstrate compliance with the HCl emission limit.

Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum chlorine fuel input or HCl emission rates. You can use the results from one fuel analysis for multiple boilers and process heaters provided they are all burning the same fuel type.

However, you must calculate chlorine fuel input, or HCl emission rate, for each boiler and process heater.

( 4) A copy of all calculations and supporting documentation of maximum TSM fuel input, using Equation 2 of § 63.7530, that were done to demonstrate continuous compliance with the TSM emission limit for sources that demonstrate compliance through performance testing. For sources that demonstrate compliance through fuel analysis, a 78 copy of all calculations and supporting documentation of TSM emission rates, using Equation 6 of § 63.7530, that were done to demonstrate compliance with the TSM emission limit.

Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum TSM fuel input or TSM emission rates. You can use the results from one fuel analysis for multiple boilers and process heaters provided they are all burning the same fuel type. However,

you must calculate TSM fuel input, or TSM emission rates,

for each boiler and process heater.

( 5) A copy of all calculations and supporting documentation of maximum mercury fuel input, using Equation 3 of § 63.7530, that were done to demonstrate continuous compliance with the mercury emission limit for sources that demonstrate compliance through performance testing. For sources that demonstrate compliance through fuel analysis, a copy of all calculations and supporting documentation of mercury emission rates, using Equation 7 of § 63.7530, that were done to demonstrate compliance with the mercury emission limit. Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum mercury fuel input or mercury emission rates. You can use the results from one fuel analysis for multiple boilers and process heaters provided they are all burning the same fuel type. However, you must calculate mercury 79 fuel input, or mercury emission rates, for each boiler and process heater.

( e) If your boiler or process heater is subject to an emission limit or work practice standard in Table 1 to this subpart and has a federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent such that the unit is in one of the limited use subcategories, you must keep the records in paragraphs ( e)( 1) and ( 2) of this section.

( 1) A copy of the federally enforceable permit that limits the annual capacity factor of the source to less than or equal to 10 percent.

( 2) Fuel use records for the days the boiler or process heater was operating.

§ 63.7560 In what form and how long must I keep my records?

( a) Your records must be 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 80 to § 63.10( b)( 1). You can keep the records off site for the remaining 3 years.

Other Requirements and Information § 63.7565 What parts of the General Provisions apply to me?

Table 10 to this subpart shows which parts of the General Provisions in § § 63.1 through 63.15 apply to you.

§ 63.7570 Who implements and enforces this subpart?

( a) This subpart can be implemented and enforced by U. S. EPA, or a delegated authority such as your State,

local, or tribal agency. If the EPA Administrator has delegated authority to your State, local, or tribal agency,

then that agency ( as well as the U. S. EPA) has the authority to implement and enforce this subpart. You should contact your 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 40 CFR part 63, subpart E, the authorities listed in paragraphs ( b)( 1) through ( 5) of this section are retained by the EPA Administrator and are not transferred to the State, local, or tribal agency, however, the U. S. EPA retains oversight of this subpart and can take enforcement actions, as appropriate.

( 1) Approval of alternatives to the non opacity emission limits and work practice standards in § 63.7500( a) 81 through ( c) under § 63.6( g).

( 2) Approval of alternative opacity emission limits in § 63.7500( a) under § 63.6( h)( 9).

( 3) Approval of major change to test methods in Table 5 to this subpart under § 63.7( e)( 2)( ii) and ( f) and as defined in § 63.90.

( 4) Approval of major change to monitoring under § 63.8( f) and as defined in § 63.90.

( 5) Approval of major change to recordkeeping and reporting under § 63.10( f) and as defined in § 63.90.

§ 63.7575 What definitions apply to this subpart?

Terms used in this subpart are defined in the Clean Air Act, in § 63.2 ( the General Provisions), and in this section as follows:

Annual capacity factor means the ratio between the actual heat input to a boiler or process heater from the fuels burned during a calendar year, and the potential heat input to the boiler or process heater had it been operated for 8,760 hours during a calendar year at the maximum steady state design heat input capacity.

Bag leak detection system means an instrument that is capable of monitoring particulate matter loadings in the exhaust of a fabric filter ( i. e., baghouse) in order to detect bag failures. A bag leak detection system includes,

but is not limited to, an instrument that operates on 82 electrodynamic, triboelectric, light scattering, light transmittance, or other principle to monitor relative particulate matter loadings.

Biomass fuel means unadulterated wood as defined in this subpart, wood residue, and wood products ( e. g., trees,

tree stumps, tree limbs, bark, lumber, sawdust, sanderdust,

chips, scraps, slabs, millings, and shavings); animal litter; vegetative agricultural and silvicultural materials,

such as logging residues ( slash), nut and grain hulls and chaff ( e. g., almond, walnut, peanut, rice, and wheat),

bagasse, orchard prunings, corn stalks, coffee bean hulls and grounds.

Blast furnace gas fuel fired boiler or process heater means an industrial/ commercial/ institutional boiler or process heater that receives 90 percent or more of its total heat input ( based on an annual average) from blast furnace gas.

Boiler means an enclosed device using controlled flame combustion and having the primary purpose of recovering thermal energy in the form of steam or hot water. Waste heat boilers are excluded from this definition.

Coal means all solid fuels classifiable as anthracite,

bituminous, sub bituminous, or lignite by the American Society for Testing and Materials in ASTM D388 77, " Standard Specification for Classification of Coals by Rank," coal 83 refuse, and petroleum coke. Synthetic fuels derived from coal for the purpose of creating useful heat including but not limited to, solvent refined coal, coal oil mixtures, and coal water mixtures, for the purposes of this subpart. Coal derived gases are excluded from this definition.

Coal refuse means any by product of coal mining or coal cleaning operations with an ash content greater than 50 percent ( by weight) and a heating value less than 13,900 kilojoules per kilogram ( 6,000 Btu per pound) on a dry basis.

Commercial/ institutional boiler means a boiler used in commercial establishments or institutional establishments such as medical centers, research centers, institutions of higher education, hotels, and laundries to provide electricity, steam, and/ or hot water.

Construction/ demolition material means waste building material that result from the construction or demolition operations on houses and commercial and industrial buildings.

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 limit, operating limit, or work practice 84 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 limit, operating limit,

or work practice standard in this subpart during startup,

shutdown, or malfunction, regardless or whether or not such failure is permitted by this subpart.

Distillate oil means fuel oils, including recycled oils, that comply with the specifications for fuel oil numbers 1 and 2, as defined by the American Society for Testing and Materials in ASTM D396 02a, " Standard Specifications for Fuel Oils."

Dry scrubber means an add on air pollution control system that injects dry alkaline sorbent ( dry injection) or sprays an alkaline sorbent ( spray dryer) to react with and neutralize acid gas in the exhaust stream forming a dry powder material. Sorbent injection systems in fluidized bed boilers and process heaters are included in this definition.

Electric utility steam generating unit means a fossil fuel fired combustion unit of more than 25 megawatts that serves a generator that produces electricity for sale. A unit that cogenerates steam and electricity and supplies more than one third of its potential electric output 85 capacity and more than 25 megawatts electrical output to any utility power distribution system for sale is considered an electric utility steam generating unit.

Electrostatic precipitator means an add on air pollution control device used to capture particulate matter by charging the particles using an electrostatic field,

collecting the particles using a grounded collecting surface, and transporting the particles into a hopper.

Fabric filter means an add on air pollution control device used to capture particulate matter by filtering gas streams through filter media, also known as a baghouse.

Federally enforceable means all limitations and conditions that are enforceable by the EPA Administrator,

including the requirements of 40 CFR parts 60 and 61,

requirements within any applicable State implementation plan, and any permit requirements established under 40 CFR 52.21 or under 40 CFR 51.18 and 40 CFR 51.24.

Firetube boiler means a boiler in which hot gases of combustion pass through the tubes and water contacts the outside surfaces of the tubes.

Fuel type means each category of fuels that share a common name or classification. Examples include, but are not limited to: bituminous coal, subbituminous coal,

lignite, anthracite, biomass, construction/ demolition material, salt water laden wood, creosote treated wood, 86 tires, residual oil. Individual fuel types received from different suppliers are not considered new fuel types except for construction/ demolition material.

Fossil fuel means natural gas, petroleum, coal, and any form of solid, liquid, or gaseous fuel derived from such materials.

Gaseous fuel includes, but is not limited to, natural gas, process gas, landfill gas, coal derived gas, refinery gas, and biogas. Blast furnace gas is exempted from this definition.

Heat input means heat derived from combustion of fuel in a boiler or process heater and does not include the heat input from preheated combustion air, recirculated flue gases, or exhaust gases from other sources such as gas turbines, internal combustion engines, kilns, etc.

Hot water heater means a closed vessel with a capacity of no more than 120 U. S. gallons in which water is heated by combustion of gaseous or liquid fuel and is withdrawn for use external to the vessel at pressures not exceeding 160 psig, including the apparatus by which the heat is generated and all controls and devices necessary to prevent water temperatures from exceeding 210

F ( 99

C).

Industrial boiler means a boiler used in manufacturing,

processing, mining, and refining or any other industry to provide steam, hot water, and/ or electricity. 87 Large gaseous fuel subcategory includes any watertube boiler or process heater that burns gaseous fuels not combined with any solid fuels, burns liquid fuel only during periods of gas curtailment or gas supply emergencies, has a rated capacity of greater than 10 MMBtu per hour heat input,

and has an annual capacity factor of greater than 10 percent.

Large liquid fuel subcategory includes any watertube boiler or process heater that does not burn any solid fuel and burns any liquid fuel either alone or in combination with gaseous fuels, has a rated capacity of greater than 10 MMBtu per hour heat input, and has an annual capacity factor of greater than 10 percent. Large gaseous fuel fired boilers and process heaters that burn liquid fuel during periods of gas curtailment or gas supply emergencies are not included in this definition.

Large solid fuel subcategory includes any watertube boiler or process heater that burns any amount of solid fuel either alone or in combination with liquid or gaseous fuels,

has a rated capacity of greater than 10 MMBtu per hour heat input, and has an annual capacity factor of greater than 10 percent.

Liquid fossil fuel means petroleum, distillate oil,

residual oil and any form of liquid fuel derived from such material. 88 Liquid fuel includes, but is not limited to, distillate oil, residual oil, waste oil, and process liquids.

Limited use gaseous fuel subcategory includes any watertube boiler or process heater that burns gaseous fuels not combined with any liquid or solid fuels, burns liquid fuel only during periods of gas curtailment or gas supply emergencies, has a rated capacity of greater than 10 MMBtu per hour heat input, and has a federally enforceable annual average capacity factor of equal to or less than 10 percent.

Limited use liquid fuel subcategory includes any watertube boiler or process heater that does not burn any solid fuel and burns any liquid fuel either alone or in combination with gaseous fuels, has a rated capacity of greater than 10 MMBtu per hour heat input, and has a federally enforceable annual average capacity factor of equal to or less than 10 percent. Limited use gaseous fuelfired boilers and process heaters that burn liquid fuel during periods of gas curtailment or gas supply emergencies are not included in this definition.

Limited use solid fuel subcategory includes any watertube boiler or process heater that burns any amount of solid fuel either alone or in combination with liquid or gaseous fuels, has a rated capacity of greater than 10 MMBtu per hour heat input, and has a federally enforceable annual average capacity factor of equal to or less than 10 percent. 89 Minimum pressure drop means 90 percent of the lowest test run average pressure drop measured according to Table 7 to this subpart during the most recent performance test demonstrating compliance with the applicable emission limit.

Minimum scrubber effluent pH means 90 percent of the lowest test run average effluent pH measured at the outlet of the wet scrubber according to Table 7 to this subpart during the most recent performance test demonstrating compliance with the applicable hydrogen chloride emission limit.

Minimum scrubber flow rate means 90 percent of the lowest test run average flow rate measured according to Table 7 to this subpart during the most recent performance test demonstrating compliance with the applicable emission limit.

Minimum sorbent flow rate means 90 percent of the lowest test run average sorbent ( or activated carbon) flow rate measured according to Table 7 to this subpart during the most recent performance test demonstrating compliance with the applicable emission limits.

Minimum voltage or amperage means 90 percent of the lowest test run average voltage or amperage to the electrostatic precipitator measured according to Table 7 to this subpart during the most recent performance test demonstrating compliance with the applicable emission 90 limits.

Natural gas means:

( 1) A naturally occurring mixture of hydrocarbon and nonhydrocarbon gases found in geologic formations beneath the earth's surface, of which the principal constituent is methane; or ( 2) Liquid petroleum gas, as defined by the American Society for Testing and Materials in ASTM D1835 82,

" Standard Specification for Liquid Petroleum Gases."

Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background.

Particulate matter means any finely divided solid or liquid material, other than uncombined water, as measured by the test methods specified under this subpart, or an alternative method.

Period of natural gas curtailment or supply interruption means a period of time during which the supply of natural gas to an affected facility is halted for reasons beyond the control of the facility. An increase in the cost or unit price of natural gas does not constitute a period of natural gas curtailment or supply interruption.

Process heater means an enclosed device using controlled flame, that is not a boiler, and the unit's primary purpose is to transfer heat indirectly to a process 91 material ( liquid, gas, or solid) or to a heat transfer material for use in a process unit, instead of generating steam. Process heaters are devices in which the combustion gases do not directly come into contact with process materials. Process heaters do not include units used for comfort heat or space heat, food preparation for on site consumption, or autoclaves.

Residual oil means crude oil, and all fuel oil numbers 4, 5 and 6, as defined by the American Society for Testing and Materials in ASTM D396 02a, " Standard Specifications for Fuel Oils."

Responsible official means responsible official as defined in 40 CFR 70.2.

Small gaseous fuel subcategory includes any firetube boiler that burns gaseous fuels not combined with any solid fuels and burns liquid fuel only during periods of gas curtailment or gas supply emergencies, and any boiler or process heater that burns gaseous fuels not combined with any solid fuels, burns liquid fuel only during periods of gas curtailment or gas supply emergencies, and has a rated capacity of less than or equal to 10 MMBtu per hour heat input.

Small liquid fuel subcategory includes any firetube boiler that does not burn any solid fuel and burns any liquid fuel either alone or in combination with gaseous 92 fuels, and any boiler or process heater that does not burn any solid fuel and burns any liquid fuel either alone or in combination with gaseous fuels, and has a rated capacity of less than or equal to 10 MMBtu per hour heat input. Small gaseous fuel fired boilers and process heaters that burn liquid fuel during periods of gas curtailment or gas supply emergencies are not included in this definition.

Small solid fuel subcategory includes any firetube boiler that burns any amount of solid fuel either alone or in combination with liquid or gaseous fuels, and any other boiler or process heater that burns any amount of solid fuel either alone or in combination with liquid or gaseous fuels and has a rated capacity of less than or equal to 10 MMBtu per hour heat input.

Solid fuel includes, but is not limited to, coal, wood,

biomass, tires, plastics, and other nonfossil solid materials.

Temporary boiler means any gaseous or liquid fuel fired boiler that is designed to, and is capable of, being carried or moved from one location to another. A temporary boiler that remains at a location for more than 180 consecutive days is no longer considered to be a temporary boiler. Any temporary boiler that replaces a temporary boiler at a location and is intended to perform the same or similar function will be included in calculating the consecutive 93 time period.

Total selected metals means the combination of the following metallic HAP: arsenic, beryllium, cadmium,

chromium, lead, manganese, nickel and selenium.

Unadulterated wood means wood or wood products that have not been painted, pigment stained, or pressure treated with compounds such as chromate copper arsenate,

pentachlorophenol, and creosote. Plywood, particle board,

oriented strand board, and other types of wood products bound by glues and resins are included in this definition.

Watertube boiler means a boiler in which water passes through the tubes and hot gases of combustion pass over the outside surfaces of the tubes.

Waste heat boiler means a device that recovers normally unused energy and converts it to usable heat. Waste heat boilers incorporating duct or supplemental burners that are designed to supply 50 percent or more of the total rated heat input capacity of the waste heat boiler are not considered waste heat boilers, but are considered boilers.

Waste heat boilers are also referred to as heat recovery steam generators.

Wet scrubber means any add on air pollution control device that mixes an aqueous stream or slurry with the exhaust gases from a boiler or process heater to control emissions of particulate matter and/ or to absorb and 94 neutralize acid gases, such as hydrogen chloride.

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 Clean Air Act. 95 Tables to Subpart DDDDD of Part 63 Table 1 to Subpart DDDDD of Part 63   Emission Limits and Work Practice Standards As stated in § 63.7500, you must comply with the following applicable emission limits:

If your boiler or process heater is in this subcategory... For the following pollutants... You must meet the following emission limits and work practice standards...

1. New or reconstructed large solid fuel fired a. Particulate Matter ( OR Total Selected Metals)

b. Hydrogen Chloride c. Mercury d. Carbon Monoxide 0.025 lb per MMBtu of heat input ( 0.0001 lb per MMBtu/ hr of heat input)

0.02 lb per MMBtu of heat input 0.000003 lb per MMBtu of heat input 400 ppm by volume on a dry basis corrected to 7 percent oxygen ( 30 day rolling average)

2. New or reconstructed limited use solid fuelfired a. Particulate Matter ( OR Total Selected Metals)

b. Hydrogen Chloride c. Mercury d. Carbon Monoxide 0.025 lb per MMBtu of heat input ( 0.0001 lb per MMBtu/ hr of heat input)

0.02 lb per MMBtu of heat input 0.000003 lb per MMBtu of heat input 400 ppm by volume on a dry basis corrected to 7 percent oxygen ( 30 day rolling average) 96 If your boiler or process heater is in this subcategory... For the following pollutants... You must meet the following emission limits and work practice standards...

3. New or reconstructed small solid fuel fired a. Particulate Matter ( OR Total Selected Metals)

b. Hydrogen Chloride c. Mercury 0.025 lb per MMBtu of heat input ( 0.0001 lb per MMBtu/ hr of heat input)

0.02 lb per MMBtu of heat input 0.000003 lb per MMBtu of heat input 4. New or reconstructed large liquid fuel fired a. Particulate Matter b. Hydrogen Chloride c. Carbon Monoxide 0.03 lb per MMBtu of heat input 0.0005 lb per MMBtu of heat input 400 ppm by volume on a dry basis corrected to 3 percent oxygen ( 30 day rolling average)

5. New or reconstructed limited use liquid fuelfired a. Particulate Matter b. Hydrogen Chloride c. Carbon Monoxide 0.03 lb per MMBtu of heat input 0.0009 lb per MMBtu of heat input 400 ppm by volume on a dry basis corrected to 3 percent oxygen ( 30 day rolling average)

6. New or reconstructed small liquid fuel fired a. Particulate Matter b. Hydrogen Chloride 0.03 lb per MMBtu of heat input 0.0009 lb per MMBtu of heat input 7. New or reconstructed large gaseous fuel fired a. Carbon Monoxide 400 ppm by volume on a dry basis corrected to 3 percent oxygen ( 30 day rolling average)

8. New or reconstructed limited use gaseous fuelfired a. Carbon Monoxide 400 ppm by volume on a dry basis corrected to 3 percent oxygen ( 30 day rolling average) 97 If your boiler or process heater is in this subcategory... For the following pollutants... You must meet the following emission limits and work practice standards...

9. Existing large solid fuel fired a. Particulate Matter ( OR Total Selected Metals)

b. Hydrogen Chloride c. Mercury 0.07 lb per MMBtu of heat input ( 0.001 lb per MMBtu/ hr of heat input)

0.09 lb per MMBtu of heat input 0.000009 lb per MMBtu of heat input 10. Existing limited use solid fuelfired a. Particulate Matter ( OR Total Selected Metals) 0.21 lb per MMBtu of heat input ( 0.004 lb per MMBtu/ hr of heat input) 98 Table 2 to Subpart DDDDD of Part 63   Operating Limits for Boilers and Process Heaters with Particulate Matter Emission Limits As stated in § 63.7500, you must comply with the applicable operating limits:

If you demonstrate compliance with applicable particulate matter emission limits using... You must meet these operating limits...

1. Wet scrubber control a. Maintain the minimum pressure drop and liquid flow rate at or above the operating levels established during the performance test according to § 63.7530( c) and Table 7 of this subpart that demonstrated compliance with the applicable emission limit for particulate matter.

2. Fabric filter control a. Install and operate a bag leak detection system according to § 63.7525 and operate the fabric filter such that the bag leak detection system alarm does not sound more than 5 percent of the operating time during each 6 month period; OR b. This option is for boilers and process heaters that operate dry control systems. Existing boilers and process heaters must maintain opacity to less than or equal to 20 percent ( 6 minute average) except for one 6 minute period per hour of not more than 27 percent. New boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity ( 1 hour block average). 99 If you demonstrate compliance with applicable particulate matter emission limits using... You must meet these operating limits...

3. Electrostatic precipitator control a. This option is for boilers and process heaters that operate dry control systems. Existing boilers and process heaters must maintain opacity to less than or equal to 20 percent ( 6 minute average) except for one 6 minute period per hour of not more than 27 percent. New boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity ( 1 hour block average).; OR b. This option is only for boilers and process heaters that operate additional wet control systems. Maintain the minimum voltage and secondary current or total power input of the electrostatic precipitator at or above the operating limits established during the performance test according to § 63.7530( c) and Table 7 of this subpart that demonstrated compliance with the applicable emission limit for particulate matter.

4. Any other control type This option is for boilers and process heaters that operate dry control systems. Existing boilers and process heaters must maintain opacity to less than or equal to 20 percent ( 6 minute average) except for one 6 minute period per hour of not more than 27 percent. New boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity ( 1 hour block average). 100 Table 3 to Subpart DDDDD of Part 63   Operating Limits for Boilers and Process Heaters With Mercury Emission Limits and Boilers and Process Heaters That Choose the Alternative Total Selected Metals Emission Limits As stated in § 63.7500, you must comply with the applicable operating limits:

If you demonstrate compliance with applicable mercury and/ or total selected metals emission limits using... You must meet these operating limits...

1. Wet scrubber control Maintain the minimum pressure drop and liquid flow rate at or above the operating levels established during the performance test according to § 63.7530( c) and Table 7 of this subpart that demonstrated compliance with the applicable emission limits for mercury and/ or total selected metals.

2. Fabric filter control a. Install and operate a bag leak detection system according to § 63.7525 and operate the fabric filter such that the bag leak detection system alarm does not sound more than 5 percent of the operating time during a 6 month period; OR b. This option is for boilers and process heaters that operate dry control systems. Existing sources must maintain opacity to less than or equal to 20 percent ( 6 minute average) except for one 6 minute period per hour of not more than 27 percent. New sources must maintain opacity to less than or equal to 10 percent opacity ( 1 hour block average). 101 If you demonstrate compliance with applicable mercury and/ or total selected metals emission limits using... You must meet these operating limits...