SMALL ENTITY COMPLIANCE GUIDE
FOR
MAJOR SOURCE BOILERS
AND
PROCESS HEATERS
National Emission Standards for Hazardous Air Pollutants for Major Sources:
Industrial, Commercial, and Institutional Boilers and Process Heaters
40 CFR Part 63, Subpart DDDDD
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NOTICE
This guide was prepared pursuant to section 212 of the Small Business Regulatory Enforcement
Fairness Act of 1996 (SBREFA), Pub. L. 104-121 as amended by Pub. L. Number 110-28. THIS
DOCUMENT IS NOT INTENDED, NOR CAN IT BE RELIED UPON, TO CREATE ANY
RIGHTS ENFORCEABLE BY ANY PARTY IN LITIGA TION WITH THE UNITED STA TES. The
statements in this document are intended solely as guidance to aid you in complying with the
NESHAP for Major Sources: Industrial, Commercial, and Institutional Boilers and Process
Heaters, 40 CFR Part 63, Subpart DDDDD.
The full text of the rule and additional information are available online at
http://www.epa.gov/ttn/atw/boiler/boilerpg.html
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ABOUT THIS GUIDE
The U.S. Environmental Protection Agency (EPA) published this document as a compliance
guide for small entities, as required by the Small Business Regulatory Enforcement Fairness Act.
The guide is designed to help small businesses determine if and how they are affected by the
National Emission Standards for Hazardous Air Pollutants (NESHAP) for Major Sources:
Industrial, Commercial, and Industrial Boilers and Process Heaters, commonly, and throughout
this document, referred to as the "Boiler MACT."
Who should use this guide?
If you own or operate a boiler or process heater, then you should use this guide. This guide will
help you determine if and how your boiler or process heater is affected by the Boiler MACT.
How do I use this guide?
This guide is organized into four major sections:
• SECTION 1: INTRODUCTION presents three rules that were published on March 21,
2011 and amended in early 2013 that affect owners and operators of boilers, process
heaters, and incinerators that burn solid waste at industrial and commercial facilities. The
section presents an overview of the rules, identifies the types of affected sources, and
presents the current status of the rules.
• SECTION 2: SUMMARY OF THE BOILER MACT RULE summarizes the
requirements of the Boiler MACT.
• SECTION 3: HOW TO COMPLY helps you determine your subcategory, which is
based on your boiler's fuel, type, and date of construction. The section also describes five
overall tasks that you have to complete, depending on your subcategory.
• SECTION 4: OTHER INFORMATION presents the estimated benefits and costs of
the Boiler MACT, provides compliance assistance resources, and tells you where to
obtain additional information on the rule.
This guide is intended to summarize rule requirements and provide some examples and
clarifications where EPA anticipates that small entities will have questions about rule
requirements. Throughout this guide, citations to the actual regulatory text are referenced for
both the Boiler MACT and the applicable overarching requirements from the General Provisions.
You can use the Electronic Code of Federal Regulations (e-CFR) to find the appropriate sections
regulatory language cited in this guide.
• To access the e-CFR regulatory text for the Boiler MACT or for the General
Provisions go to: www.ecfr.gov.
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TABLE OF CONTENTS
Page
1.0 INTRODUCTION 1
1.1 Background on Boilers and CISWI Rules 1
1.2 Rule Reconsideration 2
2.0 SUMMARY OF THE BOILER MACT 2
2.1 Who is affected by this rule? 2
2.2 Am I subject to this rule? 2
2.3 Summary of Requirements 3
2.4 When Do I Need to Comply? 8
3.0 HOW TO COMPLY 11
3.1 How Do I Determine my Subcategory? 122
3.1.1 Fuel and Design Type Subcategory 122
3.1.2 New vs. Existing Sources 155
3.1.3 Unit Size 155
3.1.4 Annual Capacity Factor 16
3.2 Which Tasks Must I Complete? 166
3.3 Task 1: Submit Initial Notifications 166
3.4 Task2: Comply with Work Practice Standards 199
3.4.1 Startup/Shutdown Procedures 199
3.4.2 Conduct Tune-ups 199
3.4.3 Conduct an Energy Assessment 222
3.5 Task 3: Meet Emission Limits 233
3.5.1 What, When, and How Must I Monitor or Test? 233
3.5.2 Minimize Emissions During Startup and Shutdown 255
3.5.3 Develop and Follow a Site-specific Testing Plan 255
3.5.4 Develop and Follow a Site-specific Monitoring Plan 255
3.5.5 Develop and Follow a Site-specific Fuel Monitoring Plan 26
3.5.6 Develop and Follow an Implementation Plan For Emission
Averaging 26
3.5.7 Conduct Initial and Annual Performance Tests 267
3.5.8 Conduct Initial and Subsequent Fuel Analysis for Each Type of Fuel....288
3.5.9 Establish Operating Limits during the Performance Test 299
3.5.10 Monitor and Collect Data to Demonstrate Continuous Compliance
with the Emission Limits 30
3.5.11 Conduct Performance Evaluations of Your Continuous Monitoring
System(s) 33
3.6 Task 4: What Records Must I Keep and for How Long? 333
3.6.1 General Requirements for Records and Certifications 333
3.6.2 Work Practice Standards Recordkeeping 366
3.6.3 Emission Limits Recordkeeping 367
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3.7 Task 5: Submit Other Notifications and Reports 399
3.7.1 Commencing or Recommencing Combustion of Solid Waste 399
3.7.2 Switching Fuels 399
3.7.3 Notification of Affirmative Defense 399
3.7.4 Tune-up and Energy Assessment Reporting: 40
3.7.5 Stack Test Performance Data Reporting: 40
4.0 OTHER INFORMATION 41
4.1 Benefits and Costs 41
4.2 Compliance Assistance Resources 41
4.3 Other Governmental Support 42
4.4 What Other Resources are Available? 43
4.5 For More Information 43
APPENDIX 44
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LIST OF TABLES
Page
Table 1: Summary of Boiler MACT Emission Limits and Work Practice Requirements 4
Table 2: Required Emission Limits for Major Source Boilers and Process Heaters 5
Table 3: Summary of Compliance Dates 9
Table 4: Notification of Compliance Status: Certifications and Other Requirements 188
Table 5: Tune-up Requirements 2Error! Bookmark not defined.
Table 6: Energy Assessment Duration Requirements 233
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
1.0 INTRODUCTION
1.1 Background on Boilers and CISWI Rules
This section will help you determine what regulations cover different types of boilers.
EPA published three final air emissions standards in the Federal Register on March 21, 2011.
They will reduce emissions of air pollutants from:
• Boilers and process heaters at major sources of air toxics ("major sources")
• Boilers not at major sources of air toxics ("area sources")
• Commercial and Industrial Solid Waste Incinerators (CISWI)
Under the Clean Air Act, EPA classifies sources by the amount of toxic pollution they emit. A
"major source" facility emits 10 or more tons per year of any single air toxic (i.e., hazardous air
pollutant) or 25 or more tons per year of any combination of hazardous air pollutants (HAP).
Any facilities that are not major sources are classified as area sources.
For more information on how to estimate the amount of emissions from your source, see the
EPA Emission Inventory Improvement Program document, "Preferred and Alternative Methods
for Estimating Air Emissions from Boilers"
(http://www.epa.gov/ttn/chief/eiip/techreport/volume02/ii02.pdf). Chapters 4 and 5 show
emissions calculation methods.
Boilers burn coal and other substances such as oil, biomass (e.g., wood), or natural gas to
produce steam or hot water, which is then used to generate energy or for heating.
Process heaters burn fuels indirectly to heat a process material (liquid, gas, or solid) for use in a
process unit. Process heaters are devices in which the combustion gases do not come into direct
contact with process materials.
The majority of major source boilers and process heaters are located at industrial facilities
such as refineries, chemical and manufacturing plants, and paper mills. However, some also
provide heat for commercial facilities, such as warehouses, or institutional facilities, such as
universities.
In contrast, the majority of area source boilers are located at commercial and institutional
facilities, such as medical centers, schools, or municipal buildings. But, area source boilers can
also be used in manufacturing, processing, mining, refining, or any other industry.
Boilers or process heaters that combust any material identified as a non-hazardous solid
waste are subject to air emission standards for incinerators rather than for boilers, with limited
exceptions. This means that owners or operators must first determine whether the combustion
unit is subject to one of the boiler standards or to the incinerator standards.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Boilers at commercial and industrial facilities that combust solid waste are most likely subject to
air emission standards for Commercial and Industrial Solid Waste Incinerators (CISWI). The
CISWI rule does not differentiate between major and area sources. More information on this
rule can be found at http://www.epa.gov/ttn/atw/129/ciwi/ciwipg.html.
1.2 Rule Reconsideration
On March 21, 2011, EPA announced that it planned to reconsider the major and area source
boiler rules, as well as the CISWI rule. This allowed EPA time to seek and review additional
public input on the final standards for boilers and certain solid waste incinerators. The agency
reconsidered the standards because the public did not have sufficient opportunity to comment on
some of the provisions of the final rules. As a result, further public review and feedback was
required to meet the legal obligations under the Clean Air Act. On January 31, 2013, the EPA
published in the Federal Register amendments to the March 21, 2011 final Boiler MACT rule.
These amendments addressed specific issues and provisions the EPA had identified for
reconsideration.
Amendments to the Boiler Area Source NESHAP were published in the Federal Register on
February 1, 2013.
Amendments to the CISWI rule were published in the Federal Register on February 7, 2013.
2.0 SUMMARY OF THE BOILER MACT
2.1 Who is affected by this rule?
The Boiler MACT rule covers boilers and process heaters located at major source facilities that
burn coal, oil, biomass, natural gas, or other solid, liquid, and gaseous non-waste materials.
Most boilers and process heaters covered by the Boiler MACT are located at industrial facilities,
with a smaller amount in the commercial and institutional sectors.
The Boiler MACT rule does NOT apply to boilers and process heaters that burn any solid waste.
Industrial boilers are found in manufacturing, processing, mining, refining or any other industry.
Commercial boilers include those found in amusement parks and stores/malls. Institutional
boilers are found in many locations, including medical centers (hospitals), educational facilities
(universities), military installations, and municipal buildings (courthouses, prisons).
2.2 Am I subject to this rule?
You are subject to the Boiler MACT if you own or operate an industrial, commercial, or
institutional boiler or process heater that is located at, or is part of, a facility that is classified as a
major source of hazardous air pollutants (HAP).
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Reminder: Although this j
guidance document provides j
sample calculations for j
estimating emissions from j
boilers, you must estimate the j
emissions from all HAP- j
emitting combustion j
equipment and processes at j
your facility to determine {
whether your source is major j
or area. j
1
http://www.epa.gov/ttn/chief/eiip/techreport/volume02/ii02.pdf. Chapters 4 and 5 provide
information on how to estimate emissions from your source.
The following major source units are NOT subject to the Boiler MACT:
• An electric utility steam generating unit (EGU) covered by subpart UUUUU of part 63
(i.e., the MATS rule).
• Hot water heaters with a capacity of no more than 120 U.S. gallons or a hot water boiler
with a heat input capacity of 1.6 million British thermal units per hour (MMBtu/hr) or
less.
• Waste heat boilers, also known as heat recovery steam generators (these boilers recover
traditionally unused energy and convert it to usable heat).
• Boilers that are used as control devices for other NESHAP standards, where at least 50
percent of the heat input to the boiler is provided by the NESHAP regulated gas stream.
• Research and development boilers.
• Boilers subject to other NESHAP standards, Section 129 standards, or hazardous waste
boilers.
• A recovery boiler or furnace covered by subpart MM.
• Temporary boilers.1
• Residential boilers.
2.3 Summary of Requirements
The EPA is regulating major source boilers and process heaters based on four components: the
type of fuel burned, whether the unit is new or existing, the design type of the unit, and the size
1 Temporary boiler means any gaseous or liquid fuel boiler that is designed to, and is capable of, being carried or
moved from one location to another. A boiler is not a temporary boiler if the boiler remains at a location within the
facility and performs the same or similar function for more than 12 consecutive months.
2 Residential boiler means a boiler used to provide heat and/or hot water for a dwelling containing four or fewer
families, or a single unit residence dwelling that has since been converted or subdivided into condominiums or
apartments.
A "major source" HAP facility emits 10 or more tons per year
of any single air toxic or 25 or more tons per year of any
combination of air toxics. The list of air toxics is available on
the EPA website at:
http://www.epa.gov/ttnatwO 1 /orig 189.html. Any facilities that
are not major sources of HAP are classified as area sources.
See the EPA Emission Inventory Improvement Program
document, "Preferred and Alternative Methods for Estimating
Air Emissions from Boilers," at:
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
of the unit. Boilers are designed differently depending on what kind of fuel they burn- coal, oil,
biomass, or gas. The final rule sets different requirements for boilers and process heaters based
on their size, which is defined as follows:
• Large major source boilers and process heaters have a heat input capacity equal to or
greater than 10 million British thermal units per hour (MMBtu/hr).
• Small major source boilers and process heaters have a heat input capacity less than 10
MMBtu/hr.
• Existing units commenced construction on or before June 4, 2010.
• New units commenced construction after June 4, 2010.
Table 1: Summary of Boiler MACT Emission Limits and Work Practice Requirements
Subcategory
Summary of Requirement
Existing large
major source
boilers and
process
heaters
i.e., commenced construction
or reconstruction of the unit
on or before June 4, 2010;
heat input capacity of 10
MMBtu/hr or greater
Clean Gas
(Natural gas,
refinery gas)
• Tune-up every year3
• One-time energy assessment
• No numeric emission limits
Coal, Biomass,
Oil, and
Process Gas
• Numeric emission limits for
mercury (Hg), carbon monoxide
(CO), hydrogen chloride (HCI), and
either particulate matter (PM) or
total selected metals (TSM)b
• Tune-up every year3
• One-time energy assessment
Limited-Usec
• Tune-up every 5 years
• No numeric emission limits
Existing small
major source
boilers and
process
heaters
i.e., commenced construction
or reconstruction of the
boiler on or before June 4,
2010; less than 10 MMBtu/hr
Coal, Biomass,
Oil, and Gas
• Tune-up every other yeard
• No numeric emission limits
• One-time energy assessment
Limited-Use
• Tune-up every 5 years
• No numeric emission limits
New large
major source
boilers and
process
heaters
i.e., commenced
construction/reconstruction
after June 4, 2010; 10
MMBtu/hr or greater
Clean Gas
(Natural gas,
refinery gas)
• Tune-up every year3
• No numeric emission limits
Coal, Biomass,
Oil, and
Process Gas
• Numeric emission limits for Hg,
CO, HCI, and PM (orTSM)b
• Tune-up every year3
Limited-Use
• Tune-up every 5 years
• No numeric emission limits
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Subcategory
Summary of Requirement
New small
major source
boilers and
process
heaters
i.e., commenced
construction/reconstruction
after June 4, 2010; less than
10 MMBtu/hr
Coal, Biomass,
Oil, and Gas
• Tune-up every other yeard
• No numeric emission limits
Limited-Use
• Tune-up every 5 years
• No numeric emission limits
a Except for boilers and process heaters with continuous oxygen trim system which conduct a tune-up every 5 years.
b Total selected metals (TSM) means the sum of the following metallic hazardous air pollutants: arsenic, beryllium,
cadmium, chromium, lead, manganese, nickel and selenium.
0 Limited-use boiler or process heater means any boiler or process heater that burns any amount of solid, liquid, or
gaseous fuels and lias a federally enforceable average annual capacity factor of no more than 10 percent.
d Except for boilers or process heaters with a continuous oxygen trim system, or have a heat input capacity of less
than or equal to 5 million Btu per hour in any of the following subcategories: unit designed to burn gas 1; unit
designed to burn gas 2 (other); or unit designed to burn light liquid. These units conduct a tune-up every 5 years.
Table 2: Required Emission Limits for Major Source Boilers and Process Heaters
PM Ib/MMbtu
Hg,
HCI,
OR
Subcategory
Ib/TBtu
Lb/MMBtu
CO, ppm @ 3% 02
(TSM, Ib/MMBtu)
All new and existing
-
-
-
-
small units (<10
MMBtu/hr)
New Large Pulverized
0.8
0.022
130 (stack test)
0.0011
Coal
OR
320a (CEMS-30-day
rolling average)
OR
(0.000023)
New Large Coal-fired
0.8
0.022
130 (stack test)
0.0011
Stoker
OR
340a (CEMS-30-day
rolling average)
OR
(0.000023)
New Large Coal-fired
0.8
0.022
130 (stack test)
0.0011
Fluidized Bed
OR
230a (CEMS-30-day
rolling average)
OR
(0.000023)
New Large Coal-fired
0.8
0.022
140 (stack test)
0.0011
Fluidized Bed with
OR
OR
integrated heat
150a (CEMS-30-day
(0.000023)
exchanger
rolling average)
New Large Wet
0.8
0.022
620 (stack test)
0.030
Biomass Stoker
OR
390a (CEMS-30-day
rolling average)
OR
0.000026
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Subcategory
Hg,
Ib/TBtu
HCI,
Lb/MMBtu
CO, ppm @ 3% 02
PM Ib/MMbtu
OR
(TSM, Ib/MMBtu)
New Large Kiln-dried
Biomass Stoker
0.8
0.022
460 (stack test)
0.030
OR
0.0040
New Large Biomass
Fluidized Bed
0.8
0.022
230 (stack test)
OR
310a (CEMS-30-day
rolling average)
0.0098
OR
0.000083
New Large Biomass
Suspension Burner
0.8
0.022
2,400 (stack test)
OR
2,000a (CEMS - 10-day
rolling average)
0.030
OR
0.0065
New Large Biomass
Dutch Oven/Pile Burner
0.8
0.022
330 (stack test)
OR
520a (CEMS-10-day
rolling average)
0.0032
OR
0.000039
New Large Biomass
Fuel Cell
0.8
0.022
910 (stack test)
0.020
OR
0.000029
New Large Biomass
Hybrid Suspension
Grate
0.8
0.022
1,100 (stack test)
OR
900a (CEMS-30-day
rolling average)
0.026
OR
0.00044
New Large Heavy
Liquid
0.48
0.00044
130
0.013
OR
0.000075
New Large Light Liquid
0.48
0.00044
130
0.0011
OR
0.000029
New Large Liquid Non-
continental13
0.48
0.00044
130
0.023
OR
0.00086
New Large Gas 2
(other) Gasesc
7.9
0.0017
130
0.0067
OR
0.00021
Existing Large
Pulverized Coal
5.7
0.022
130 (stack test)
OR
320 a (CEMS - 30-day
rolling average)
0.040
OR
(0.000053)
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Subcategory
Hg,
Ib/TBtu
HCI,
Lb/MMBtu
CO, ppm @ 3% 02
PM Ib/MMbtu
OR
(TSM, Ib/MMBtu)
Existing Large Coal-
fired Stoker
5.7
0.022
160 (stack test)
OR
340a (CEMS-30-day
rolling average)
0.040
OR
(0.000053)
Existing Large Coal-
fired Fluidized Bed
5.7
0.022
130 (stack test)
OR
230a (CEMS-30-day
rolling average)
0.040
OR
(0.000053)
Existing Large Wet
Biomass Stoker
5.7
0.022
1,500 (stack test)
OR
720a (CEMS-30-day
rolling average)
0.037
OR
0.00024
Existing Large Kiln-
dried Biomass Stoker
0.8
0.022
460 (stack test)
0.32
OR
0.0040
Existing Large Biomass
Fluidized Bed
0.8
0.022
470 (stack test)
OR
310a (CEMS-30-day
rolling average)
0.11
OR
0.0012
Existing Large Biomass
Suspension Burner
0.8
0.022
2,400 (stack test)
OR
2,000a (CEMS - 10-day
rolling average)
0.051
OR
0.0065
Existing Large Biomass
Dutch Oven/Pile Burner
0.8
0.022
770 (stack test)
OR
520a (CEMS-10-day
rolling average)
0.28
OR
0.0020
Existing Large Biomass
Fuel Cell
0.8
0.022
1,100 (stack test)
0.020
OR
0.0058
Existing Large Biomass
Hybrid Suspension
Grate
0.8
0.022
2,800 (stack test)
OR
900a (CEMS-30-day
rolling average)
0.44
OR
0.00045
Existing Large Heavy
Liquid
2.0
0.0011
130
0.062
OR
0.00020
Existing Large Light
Liquid
2.0
0.0011
130
0.0079
OR
0.000062
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
PM Ib/MMbtu
Hg,
HCI,
OR
Subcategory
Ib/TBtu
Lb/MMBtu
CO, ppm @ 3% 02
(TSM, Ib/MMBtu)
Existing Large Liquid
2.0
0.0011
130
0.27
Non-continentalb
OR
0.00086
Existing Large Gas 2
7.9
0.0017
130
0.0067
(other) Gasesc
OR
0.00021
a To demonstrate compliance with the applicable alternative CO CEMS emission standard, you must install, certify,
operate, and maintain a CO CEMS and an oxygen analyzer.
b A non-continental unit means an industrial, commercial, or institutional boiler or process heater meeting the
definition of the unit designed to burn liquid subcategory located in the State of Hawaii, the Virgin Islands, Guam,
American Samoa, the Commonwealth of Puerto Rico, or the Northern Mariana Islands.
0 Gas 2 (other) Gases are gaseous fuels other than burns only natural Gas and refinery gas.
Appendix A of this guide also provides a detailed summary of the Boiler MACT requirements by
subcategory and tasks to complement the requirements are outlined in Section 3 of this
compliance guide.
2.4 When Do I Need to Comply?
Example notification forms can be found under "Implementation Tools" at
http://www.epa.gov/ttn/atw/boiler/boilerpg.html. and include information on compliance
assistance contacts. Notification forms are not required to be submitted electronically.
Initial Notification of Applicability: (§63.9(b)(2))
• May 31, 2013, if startup was before January 31, 2013 (§63.7545(b))
• If startup is on or after January 31, 2013, then within 15 days after startup (§63.7545(c))
Compliance Dates (§63.7495)
• New Sources (constructed or reconstructed after June 4, 2010) must comply by January
31, 2013 or upon startup, whichever is later.
• Existing sources must comply by January 31, 2016
• Existing area sources that become major sources must comply within 3 years from the
date the source becomes a major source.
Initial Notification of Compliance Status: (§63.7545(e)-(h))
You may be required to submit any of the below notification forms. See Section 3.3 for more
details.
• If your source must conduct a performance test, a Notification of Intent must be
submitted at least 60 days before the performance test is scheduled to begin.
(§63.7545(d)).
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
• If your source is required to conduct initial compliance demonstrations, you must submit
a Notification of Compliance Status form, including all performance test results and fuel
analyses, before the close of business on the 60th day following the completion of all
performance tests and/or other initial compliance demonstrations. (§63.7545(e)).
• If you operate a unit designed to burn natural gas, refinery gas, or other gas 1 fuels and
you intend to use a different gaseous fuel subject to another regulation or another gas 1
fuel to fire the unit during a period of natural gas curtailment or supply interruption (as
defined in § 63.7575), you must submit a Notification of Alternative Fuel Use within 48
hours of the declaration of each period of natural gas curtailment or supply interruption.
(§63.7545(f)).
• If you intend to burn solid waste, you must provide 30 days notice prior to the date when
you will commence or recommence combustion of solid waste. (§63.7545(g).
• If you have switched fuels or made a physical change to the boiler and the change caused
the unit to fall under a different subcategory of the rule, you must provide notice of the
change within 30 days. (§63.7545(h).
Table 3: Summary of Compliance Dates
Subcategory
Submit Initial
Notification
of
Applicability
by...
Submit Initial
Notification of
Compliance
Status by...
Complete
Initial
Tune-ups
by...
Complete
Energy
Assessment
by...
Demonstrate
Compliance
with
Emission
Limits by...
Prepare
Compliance
Certification
Report by...
Existing Large (10 MMBtu/hr and greater)
All Existing
Large Units
other than
Gas 1 Units
5/31/2013
Within 60 days
following
completion of
all performance
tests and/or
other
compliance
demonstrations
1/31/2016
1/31/2016
7/29/2016
1st report
submitted by
1/31/2017.
Semiannual
reports
submitted July
31 or January 31
(first date after
semiannual
reporting
period3)
3 Other gas 1 fuel means a gaseous fuel that is not natural gas or refinery gas and does not exceed a maximum
mercury concentration of 40 micrograms/cubic meter.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 3: Summary of Compliance Dates
Subcategory
Submit Initial
Notification
of
Applicability
by...
Submit Initial
Notification of
Compliance
Status by...
Complete
Initial
Tune-ups
by...
Complete
Energy
Assessment
by...
Demonstrate
Compliance
with
Emission
Limits by...
Prepare
Compliance
Certification
Report by...
All Existing
Large Gas 1
Units
5/31/2013
Within 60 days
following
completion of
all compliance
demonstrations
1/31/2016
1/31/2016
-
1st report
submitted by
1/31/2017.
Annual or 5-year
compliance
reports
submitted by
January 31
Existing Small (< 10 MMBtu/hr)
All Existing
Small Units
and Limited-
Use Units
5/31/2013
Within 60 days
following
completion of
all compliance
demonstrations
1/31/2016
1/31/2016
-
1st report
submitted by
1/31/2017.
Annual,
biennial, or 5-
year compliance
reports
submitted by
January 31
New Large (10 MMBtu/hr or greater)
New Large
Units other
than Gas 1
Units
5/31/2013 or
within 15
days of
startup if
actual startup
on or after
1/31/2013
Within 60 days
following
completion of
all performance
test and/or
other
compliance
demonstrations
-
-
7/30/2013 or
within 180
days after
startup,
whichever is
later
1st report
submitted by
July 31 or
January 31 (first
date after the
end of the first
calendar year
half after the
compliance
date)
Semiannual
reports
submitted by
July 31 or
January 31 (first
date after
semiannual
reporting
period3)
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 3: Summary of Compliance Dates
Subcategory
Submit Initial
Notification
of
Applicability
by...
Submit Initial
Notification of
Compliance
Status by...
Complete
Initial
Tune-ups
by...
Complete
Energy
Assessment
by...
Demonstrate
Compliance
with
Emission
Limits by...
Prepare
Compliance
Certification
Report by...
New Large
Gas 1 Units
5/31/2013 or
within 15
days of
startup if
actual startup
on or after
1/31/2013
-
-
-
-
1st report
submitted by
January 31 that
is at least 1 or 5
years after the
compliance
date. Annual or
5-year reports
submitted by
January 31
New Small (> 10 MMBtu/hr)
All New
Small Units
and Limited-
Use Units
5/31/2013 or
within 15
days of
startup if
actual startup
on or after
1/31/2013
-
-
-
-
1st report must
be submitted by
January 31 that
is at least 1, 2,
or 5 years, after
the compliance
date. Annual,
biennial, or 5-
year compliance
reports
submitted by
January 31
a The semiannual reporting periods are from January 1 through June 30 and from July 1 through December 31.
3.0 HOW TO COMPLY
Appendix A of this guide summarizes what you must do to comply. Your requirements depend
on the subcategory of your boiler or process heater. To determine your requirements, take the
following steps:
1. Determine your subcategory using the six questions in the next section.
2. Based on your subcategory, determine which tasks you must complete.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
3.1 How Do I Determine my Subcategory?
To determine your subcategory, you must answer six questions:
• What fuels are combusted in my boiler or process heater?
• What design type is my boiler or process heater?
• What percentage of the annual heat input is supplied by each fuel type?
• Is my boiler or process heater a new source or an existing source?
• What size is my boiler or process heater?
• What is the annual capacity factor of the boiler or process heater?
3.1.1 Fuel and Design Type Subcategory
You must determine your subcategory on an annual heat input basis, or the actual heat input for
all the fuels combusted during the 12 months preceding the tune-up or compliance test. The
following steps provide an example calculation for an annual heat input basis, as well as a list of
suitable methods for determining the appropriate fuel subcategory for your boiler or process
heater. First we provide some definitions used in the steps below and definitions of the different
combustor designs.
Annual heat input basis means the actual heat input for fuels combusted during the 12 months
preceding the tune-up or compliance test.
Biomass subcategories: Includes any boiler or process heater that burns at least 10 percent
biomass on an annual heat input basis.
Coal subcategories: Includes any boiler or process heater that burns at least 10 percent solid
fossil fuel (e.g., coal, petroleum coke, tire derived fuel) and no more than 10 percent biomass on
an annual heat input basis.
Liquid fuel subcategories: Includes any boiler and process heater that burns any liquid fuel, no
more than 10 percent solid fossil fuels, and no more than 10 percent biomass on an annual heat
input basis.
Gas 1 subcategory: Includes any boiler or process heater that burns only natural gas, refinery
gas, or other gas 1 fuels with the exception of liquid fuels burned during gas curtailments and
supply emergencies or for periodic testing (not to exceed 48 hours in a calendar year).
Gas 2 subcategory: Includes any boiler or process heater that is not in the Gas 1 subcategory
and burns any gaseous fuels in combination with less than 10 percent solid fossil fuel, less than
10 percent biomass, and less than 10 percent liquid fuel on an annual heat input basis.
Pulverized coal subcategory: Pulverized coal boiler means a boiler in which pulverized coal or
other solid fossil fuel is introduced into an air stream that carries the fuel to the combustion
chamber of the boiler where it is fired in suspension.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Stoker subcategories: Stoker means a unit consisting of a mechanically operated fuel feeding
mechanism, a stationary or moving grate to support the burning of fuel and admit under-grate air
to the fuel, an overfire air system to complete combustion, and an ash discharge system.
Fluidized bed subcategories: Fluidized bed boiler means a boiler using a fluidized bed
combustion process that is not a pulverized coal boiler. Fluidized bed combustion is a process
where a fuel is burned in a bed of granulated particles which are maintained in a mobile
suspension by the upward flow of air and combustion products.
Suspension burner subcategory: Suspension burner means a unit designed to fire dry biomass
solid particles that are blown into the furnace like in the pulverized coal subcategory.
Combustion of the fuel material is completed on a grate or floor below. The biomass fuel
combusted in the unit shall not exceed 20 percent moisture on an annual heat input basis.
Dutch Oven/Pile burner subcategory: Dutch oven means a unit having a refractory-walled cell
connected to a conventional boiler. Fuel materials enter through an opening in the roof of the
dutch oven and burn in a pile on its floor. Pile burner means a boiler design where the fuel has a
high relative moisture content (typically biomass). Grates support the fuel allowing underfire air
to flow up through the grates and provide oxygen for combustion, cool the grates, promote
turbulence in the fuel bed, and fire the fuel.
Fuel Cell subcategory: Fuel cell means a boiler where the fuel is dropped onto suspended fixed
grates and is fired in a pile. The refractory-lined fuel cell uses combustion air preheating and
positioning of secondary and tertiary air injection ports to improve boiler efficiency.
Hybrid suspension grate subcategory: Hybrid suspension grate boiler means a boiler designed
with air distributors to spread the fuel material over the entire width and depth of the boiler
combustion zone. The biomass fuel combusted in these units exceeds moisture content of 40
percent on an as-fired basis. The drying and much of the combustion of the fuel takes place in
suspension, and the combustion is completed on the grate or floor of the boiler.
Limited-Use subcategory: Limited-use boiler or process heater means any boiler or process
heater that has a federally enforceable average annual capacity factor of no more than 10 percent.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
How do 1 determine the fuel subcategory of my boiler or process heater on an annual heat input basis ?
A boiler's or process heater's fuel subcategory is determined on an annual heat input basis using the
fuel consumed in the 12 months before the compliance demonstration. The calculation requires you to
estimate a high heat value (HHV) for each fuel. This rule provides several options to estimate HHV: you
may obtain the data from your fuel supplier, use the calculation methodologies in the EPA greenhouse
gas (GHG) reporting program (40 CFR part 98, subpart C), or conduct site-specific testing.
The following example shows the four-step process to determine the fuel category for a boiler with a
designed heat input capacity of 100 MMBtu per hour, operated 8,400 hours per year, at a load of 90%.
Step 1: Calculate an Annual Fuel Consumption Total
Bituminous Coal
(tons)
Wood and Wood
Residuals (tons)
No. 2 Fuel Oil
(gallons)
Natural Gas (cubic
feet)
January
0
0
89,930
49,259,010
February
0
0
329,610
17,053,550
March
680
2,990
0
0
April
780
2,830
0
0
May
470
3,330
0
0
June
490
3,310
0
0
July
0
0
1,830
61,098,340
August
190
3,780
0
0
September
720
2,940
0
0
October
620
3,080
0
0
November
0
0
322,300
18,035,050
December
0
0
36,070
56,497,570
Total
3,950
22,260
779,740
201,943,520
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Step 2: Multiply the Total Annual Consumption by the Heating Value of Each Fuel
The table below is an excerpt from the GHG reporting program [40 CFR Part 98 Subpart C, Table C-l
Default C02 Emission Factors and High Heat Values for Various Types of Fuel], Other published sources
of HHV may also be used.
Default High Heat Value (HHV)
(MMBtu/short ton)
(MMBtu/scf)
(MMBtu/gallon)
Bituminous Coal
24.93
-
-
Wood and Wood
15.38
-
-
Distillate Fuel Oil No. 2
-
-
0.138
Natural Gasoline
-
1.03E-03
-
Step 1 total x HHV
Bituminous Coal
Wood and Wood
Residuals
Distillate Fuel
Oil No. 2
Natural Gas
Fuel Usage
98,641
342,359
107,604
207,396
Step 3: Calculate an Annual Consumption Total for All Fuels.
All Fuels
Grand Total (mmBtu)
755,999
Step 4: Calculate an Annual Consumption Total.
Bituminous Coal
Wood and Wood
No. 2 Fuel Oil
Natural Gas
% of Total
13%
45%
14%
27%
This boiler or process heater is in the biomass subcategory because it burns at least 10% biomass on an
annual heat input basis. You should repeat these calculations before every compliance demonstration
(e.g. tune-up or performance test).
3.1.2 New vs. Existing Sources
You have an existing source if you commenced construction or reconstruction of the boiler or
process heater on or before June 4, 2010. You have commenced construction or reconstruction if
you have a contractual obligation to undertake and complete construction or have begun the act
of construction on the boiler or process heater.
You have a new source if you commenced construction or reconstruction of the boiler or process
heater after June 4, 2010 and you met the applicability criteria at the time you commenced
construction.
3.1.3 Unit Size
Boiler or process heater size is expressed in terms of rated design heat input capacity and is
measured in million British thermal units per hour, or MMBtu/hr.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
To determine the size of your boiler or process heater, check the nameplate on the boiler or
process heater. The nameplate often lists the rated heat input capacity on the unit. This rated
capacity may have also been reported to the insurer of the boiler or process heater or to the state
labor and safety inspector.
3.1.4 Annual Capacity Factor
Limited-use boiler or process heater means any boiler or process heater that burns any amount of
solid, liquid, or gaseous fuels and has a federally enforceable average annual capacity factor of
no more than 10 percent.
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 year at the maximum steady state design
heat input capacity.
3.2 Which Tasks Must I Complete?
Based on your subcategory (i.e. fuel, combustor type, new/existing, size considerations), use
Appendix A to determine which tasks you must complete. The task requirements are
summarized below.
Task 1: Submit initial notifications
Task 2: Comply with work practice standards
Task 3: Meet emission limits
Task 4: Keep records
Task 5: Submit other notifications and reports
3.3 Taskl: Submit Initial Notifications
Owners and operators of a boiler or process heater must submit an initial Notification of
Applicability and an initial Notification of Compliance Status.
See example forms at http://www.epa.gov/ttn/atw/boiler/boilerpg.html under "Implementation
Tools."
Notification of Applicability. Submit a Notification of Applicability according to the following
schedule:
Existing Sources: No later than May 31,2013.
New Sources: By January 31, 2013, or within 15 days of startup of a new source,
whichever is later.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
The Notification of Applicability must contain the following information:
• The name and address of the owner or operator.
• The address (i.e., physical location) of the affected source.
• An identification of the relevant standard, or other requirement, that is the basis of the
notification (i.e., 40 CFR part 63 subpart DDDDD) and the source's compliance date.
• Anticipated compliance date with the standard.
• A brief description of the nature, size, design, and method of operation of the source and
an identification of the types of emission points within the affected source subject to the
relevant standard and types of hazardous air pollutants emitted.
• A statement of whether the affected source is a major source or an area source.
Notification of Compliance Status. Submit the Notification of Compliance Status according to
the following schedule:
Existing Sources: No later than September 30, 2016 or within 60 days of completing
the performance test and/or other initial compliance
demonstrations, whichever is earlier
New Sources: Within 60 days of completing the performance stack test and/or
other initial compliance demonstrations.
The Notification of Compliance Status is your certification that your facility is in compliance
with all the requirements of the rule.
You must keep a copy of each notification and report that you submit to comply with this rule,
and all documentation supporting any Initial Notification of Applicability or Notification of
Compliance Status that you submitted.
Table 4 outlines the certifications and other requirements included in the Notification of
Compliance Status, as applicable, which must be signed by a responsible official to certify its
accuracy.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 4: Notification of Compliance Status: Certifications and Other Requirements
If...
...then you must include the following statement in the
Notification of Compliance Status...
You must conduct a tune-up
"This facility complies with the required initial tune-up
according to the procedures in §63.7540(a)(10)."
You must conduct an energy
assessment
"This facility has had an energy assessment performed
according to §63.7530(e)."
Your boilers do not qualify for a
statutory exemption as provided in
Section 129(g)(1) of the Clean Air Act
"No secondary materials that are solid waste were combusted
in any affected unit."
Your unit is subject to emission limits in
subpart DDDDD.a
A description of the affected unit(s) including identification of
the unit's subcategories, the design heat input capacity of the
unit, a description of the add-on controls used to comply with
this subpart, description of the fuel(s) burned, including if the
fuel(s) were a secondary material determined to be a non-
waste under § 241.3, and justification for the selection of fuel(s)
burned during the compliance demonstration.
Summary of the results of all performance tests and fuel
analyses, and calculations done to demonstrate initial
compliance including all established operating limits, and:
(i) Identification of if you are complying with the PM emission
limit or the alternative TSM emission limit.
(ii) Identification of if you are complying with the output-based
or heat input-based (i.e., lb/MMBtu or ppm) emission limits.
A summary of the maximum CO emission levels recorded
during the performance test to show you have met any
applicable emission standards in Tables 1, 2, or 11 through 13
to this subpart, if you are not using a CO CEMS for compliance.
Identification of if you plan to demonstrate compliance with
each applicable emission limit through performance testing, a
CEMS, or fuel analysis.
Identification of if you plan to demonstrate compliance by
emissions averaging or using efficiency credits through energy
conservation.
A signed certification that you have met all applicable emission
limits and work practice standards.
You had a deviation from any emission
limit, work practice standard, or
operating limit,
A description of the deviation, the duration of the deviation,
and the corrective action taken.
a If you are using data from a previously conducted emission test to serve as documentation of compliance with the
emission standards and operating limits of this rule, then you must submit the previous test data instead of the initial
performance test results with the Notification of Compliance Status.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
3.4 Task 2: Comply with Work Practice Standards
3.4.1 Startup/Shutdown Procedures
During startup, boilers and process heaters that have emission limits must:
• Operate all continuous monitoring systems (CMS) and collect monitoring data,
• Use one or a combination of the following clean fuels: natural gas, synthetic natural gas,
propane, distillate oil, syngas, ultra-low sulfur diesel, fuel oil-soaked rags, kerosene,
hydrogen, paper, cardboard, refinery gas, or liquefied petroleum gas.
• When starting to fire coal or solid fossil fuel, biomass or bio-based solids, heavy liquid
fuel, or gas 2 (other) gases, you must vent emissions to the main stack(s) and engage all
of the applicable control devices except limestone injection in fluidized bed combustion
(FBC) boilers, dry scrubbers, fabric filters, selective non-catalytic reduction (SNCR)
systems, and selective catalytic reduction (SCR) systems.
• Start limestone injection in FBC boilers, dry scrubbers, fabric filters, SNCR systems, and
SCR systems as expeditiously as possible, and
• Provide reports of activities during and periods of startup.
Startup begins either at the first-ever firing of fuel in a boiler or process heater for the purpose of
supplying steam or heat for heating and/or producing electricity, or for any other purpose, or the
firing of fuel in a boiler after a shutdown event for any purpose. Startup ends when any of the
steam or heat from the boiler or process heater is supplied for heating, and/or producing
electricity, or for any other purpose.
During shutdown, boilers and process heaters that have emission limits must:
• Operate all CMS and collect monitoring data
• While firing coal/solid fossil fuel, biomass/bio-based solids, heavy liquid fuel, or gas 2
(other) gases during shutdown, must vent emissions to the main stack(s) and operate all
applicable control devices, except limestone injection in FBC boilers, dry scrubbers,
fabric filters, SNCR systems, and SCR systems.
• Keep records of activities during periods of shutdown.
Shutdown begins either when none of the steam from the boiler is supplied for heating and/or
producing electricity, or for any other purpose, or at the point of no fuel being fired in the boiler
or process heater, whichever is earlier. Shutdown ends when there is no steam and no heat being
supplied and no fuel being fired in the boiler or process heater.
3.4.2 Conduct Tune-ups
Boilers and process heaters subject to tune-up requirements must conduct a tune-up either
annually, biennially (i.e., every 2 years), or every 5 years.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
The following boilers and process heaters are required to have an annual tune-up:
• New and existing boilers and process heaters having a heat input capacity 10 MMBtu/hr
or greater and without a continuous oxygen trim system.
The following boilers and process heaters are required to have a tune-up every 2 years:
• New or existing boiler or process heater without a continuous oxygen trim system and
with heat input capacity of less than 10 million Btu per hour in the unit designed to burn
heavy liquid or unit designed to burn solid fuel subcategories; or
• New or existing boiler or process heater with heat input capacity of less than 10 million
Btu per hour, but greater than 5 million Btu per hour, in any of the following
subcategories: unit designed to burn gas 1; unit designed to burn gas 2 (other); or unit
designed to burn light liquid.
The following boilers and process heaters are required to have a tune-up every 5 years:
• New or existing boiler or process heater with a continuous oxygen trim system that
maintains an optimum air to fuel ratio, or
• New or existing boiler or process heater with a heat input capacity of less than or equal
to 5 million Btu per hour in any of the following subcategories: unit designed to burn gas
1; unit designed to burn gas 2 (other); or unit designed to burn light liquid, or
• A limited-use boiler or process heater.
You must complete the initial tune-up by the following dates:
Existing Sources: No later than January 31, 2016
New Sources: The first annual, biennial, or 5-year tune-up must be no later than 13
months, 25 months, or 61 months, respectively, after January 31, 2013 or
the initial startup of the new or reconstructed affected source, whichever is
later.
Each annual tune-up must be done no more than 13 months after the previous tune-up. Each
biennial tune-up must be done no more than 25 months after the previous tune-up. Each 5-year
tune-up must be done no more than 61 months after the previous tune-up.
See the Tune-up Guidance and Example Recordkeeping Form at
http://www.epa.gov/ttn/atw/boiler/boilerpg.html under "Implementation Tools."
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 5: Tune-up Requirements
Requirement
Description
Notes
Inspect the burner, as
applicable
Clean or replace any burner
components as necessary
This inspection can be
delayed until the next
scheduled unit shutdown, but
you must inspect each burner
at least once every 36
months.
Inspect and optimize the
flame pattern as needed
Should be consistent with the
manufacturer's specifications,
if available
Inspect the air-to-fuel ratio
control system
Ensure correct calibration and
function
This inspection can be
delayed until the next
scheduled unit shutdown if
needed
Optimize total emissions of
CO
Should be consistent with the
manufacturer's specifications
and with any NOx
requirement.
Measure CO and oxygen
levels before and after the
tune-up adjustments are
made
Report units in parts per
million, by volume
Measurements may be either
on a dry or wet basis as long
as the same basis is used
before and after the
adjustments.
Portable CO analyzer may be
used.
Document actions and fuel
use
Maintain records of:
1) CO and oxygen levels
measured at high fire or
typical operating load before
and after tune-up, and
2) any improvements or
actions taken during the boiler
tune-up.
Maintain monthly fuel records,
for the 12 months preceding
each tune-up.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
3.4.3 Conduct an Energy Assessment
Facilities must conduct a one-time energy assessment for all existing affected boilers and process
heaters. The energy assessment includes:
1. A visual inspection of the boiler or process heater
system (e.g. cracks, corrosion, leaks).
2. An evaluation of operating characteristics of the boiler
or process heater system, specifications of energy using
systems, operating and maintenance procedures, and
unusual operating constraints.
3. Inventory of major systems consuming energy from
affected boiler(s) and process heater(s).
4. A review of available architectural and engineering
plans, facility operation and maintenance procedures
and logs, and fuel usage.
5. A review of the facility's energy management practices with recommendations for
improvements.
6. A list of cost-effective energy conservation measures.
7. A list of the energy savings potential of the energy conservation measures identified.
8. A comprehensive report detailing the ways to improve efficiency, the cost of specific
improvements, benefits, and the time frame for recouping those investments.
The energy assessment applies to only existing affected boilers and process heaters and their
energy use systems. An energy use system includes the following systems located on-site that
use energy from the affected boiler or process heater: process heating; compressed air systems;
machine drive (motors, pumps, fans); process cooling; facility heating, ventilation, and air
conditioning (HVAC) systems; hot heater systems; the building envelope, and lighting.
The boiler or process heater and its energy use systems must be evaluated to identify energy
savings opportunities, as identified in Table 6.
NOTE: An energy assessment
completed on or after January
1, 2008, that meets (or is
amended to meet) the energy
assessment requirements may
be used instead of a new
assessment.
The U.S. Department of Energy
provides additional guidance on
assessments at
http://wwwl.eere.energy.gov/
manufacturing/tech deployme
nt/energy assessment.html.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 6: Energy Assessment Duration Requirements
If your Affected Boilers and
Process Heaters have a
Combined Annual Heat Input
Capacity, as measured in Trillion
Btu/yr (TBtu/yr), of...
Then the length of the energy
assessment should not exceed1...
And the energy assessment
will include evaluation of
energy use system(s)
accounting for this percent of
the energy output from these
affected units...
Less than 0.3
8 on-site technical labor hours
At least 50%
0.3 to 1
24 on-site technical labor hours
At least 33%
Greater than 1.0
24 on-site technical labor hours
for first 1.0 TBtu/year + 8 on-site
technical labor hours for every
additional 1.0 TBtu/year, not to
exceed 160 on-site technical
labor hours
At least 20%
1 Longer assessments may be warranted at the discretion of the affected facility.
3.5 Task 3: Meet Emission Limits
3.5.1 What, When, and How Must I Monitor or Test?
Many types of major source boilers and process heaters do not have emission limits including:
• Existing and new small (<10 MMBtu/h) boilers and process heaters
• Existing and new limited-use boilers and process heaters
• Existing and new boilers and process heaters in the Gas 1 (e.g., natural gas, refinery gas)
subcategory
Your specific emission limits depend on the subcategory that applies to your boiler or process
heater (see Table 2 of this guide). Section 3.1 discusses how to determine what subcategory
applies to your boiler or process heater.
If your boiler or process heater is subject to emission limits, you must demonstrate compliance
according to the following schedule.
Initial compliance:
• Existing units: By January 31, 2016 + 180 days = July 29, 2016 (§63.7510(e))
• New units: January 31, 2013 + 180 days = July 30, 2013 or 180 days after startup,
whichever is later (§63.7510(f))
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Continuous compliance:
If your boiler or process heater is subject to emission limits, you must conduct a stack test every
year. Each subsequent test should be no more than 13 months after the previous test.
• If your performance tests for a given pollutant show emissions at or below 75 percent of
the limit for the pollutant for at least 2 consecutive years, and if there are no changes in
the operation of the boiler or process heater or air pollution control equipment that could
increase emissions, you can conduct performance tests for the pollutant every third year.
Each test must be conducted no more than 37 months after the previous performance test.
However, if you demonstrate compliance using emission averaging, you must continue to
conduct annual tests. (§63.7515(b))
• If a performance test shows emissions exceeded the emission limit or 75 percent of the
emission limit for a pollutant, you must conduct annual performance tests for that
pollutant until all tests in a consecutive 2-year period are at or below 75 percent of the
emission limit.
To demonstrate compliance with the emission limits, you must:
1. Conduct the boiler's or process heater's startup and shutdown periods to minimize
emissions according to the work practice standard.
2. Develop and follow a site-specific testing plan.
3. Develop and follow a site-specific fuel monitoring plan.
4. Develop and follow a site-specific monitoring plan.
5. Conduct initial and annual performance tests for: mercury (Hg), carbon monoxide (CO)4,
hydrogen chloride (HC1), and either particulate matter (PM) or total selected metals
(TSM).
6. Establish operating limits during the performance test.
7. Conduct initial and, if compliance based on fuel analysis, monthly fuel analysis for each
type of fuel.
8. Monitor and collect data to demonstrate compliance with the operating limits.
9. Conduct performance evaluations of your continuous monitoring system(s).
As an alternative to performance stack testing for Hg, HC1, or TSM, you may conduct a fuel
analysis to demonstrate that your fuel pollutant input is lower than the applicable emission limit.
See Section 3.5.8 of this guide for more detail.
4 Any boiler or process heater that has a CO CEMS that is compliant (i.re., certified) with Performance Specification
4, 4A, or 4B at 40 CFR part 60, appendix B must use the CO CEMS to comply with the applicable alternative CO
CEMS emission standard.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
3.5.2 Minimize Emissions During Startup and Shutdown
If your boiler or process heater is subject to an emission limit, then you must minimize emissions
during startup and shutdown periods per the work practice procedures.
• Operate all CMS to collect monitoring data during periods of startup and shutdown,
• During startup use one or a combination of the following clean fuels: natural gas,
synthetic natural gas, propane, distillate oil, syngas, ultra-low sulfur diesel, fuel oil-
soaked rags, kerosene, hydrogen, paper, cardboard, refinery gas, and liquefied petroleum
gas.
• Vent emissions to the main stack(s) and engage all of the applicable control devices
[except limestone injection in fluidized bed combustion (FBC) boilers, dry scrubber,
fabric filter, selective non-catalytic reduction (SNCR), and selective catalytic reduction
(SCR)] when firing coal/solid fossil fuel, biomass/bio-based solids, heavy liquid fuel, or
gas 2 (other) gases.
• Start limestone injection in FBC boilers, dry scrubber, fabric filter, SNCR, and SCR
systems as expeditiously as possible.
3.5.3 Develop and Follow a Site-specific Testing Plan (§63.7520(a))
You must develop a site-specific test plan before conducting a required performance test. You do
not have to submit the site-specific test plan to the EPA Administrator or delegated authority
unless it is requested. You must keep a copy of the site-specific test plan as a record.
The site-specific test plan must include:
• Test program summary
• Test schedule
• Data quality objectives (pretest expectations of precisions, accuracy, and completeness)
• Internal and external quality assurance program.
3.5.4 Develop and Follow a Site-specific Monitoring Plan (§63.7505(d))
If you demonstrate compliance through performance stack
with operating limits, then you must develop a site-
specific monitoring plan. The monitoring plan is
required for any continuous emissions monitoring
system (CEMS), continuous opacity monitoring system
(COMS), or continuous parameter monitoring system
(CPMS). Collectively, these three types of continuous
monitors are referred to as continuous monitoring
systems (CMS) in the remainder of this section. A
monitoring plan is also required if you petition the EPA
testing and subsequent compliance
Can I Use an Existing Monitoring
Plan?
A site-specific monitoring plan is not
required if you have existing plans
prepared under Appendix B to part 60
that apply to CEMS and COMS and meet
the monitoring, installation, operation,
and maintenance requirements of the
Boiler MACT rule.
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Administrator for alternative monitoring parameters under §63.8(f) of the General Provisions. In
general, you must:
• Submit this site-specific monitoring plan at least 60 days before your initial performance
evaluation of your CMS, if requested.
• Address §63.11205(c)(l)(i) through (vi) in your plan, which includes installation
location, ongoing operation and maintenance procedures, ongoing data quality assurance
procedures, and ongoing data quality assurance procedures.
• Conduct a performance evaluation of each CMS as outlined in your site-specific
monitoring plan.
• Operate and maintain the CMS according to the site-specific monitoring plan.
3.5.5 Develop and Follow a Site-specific Fuel Monitoring Plan (§63.7521(b))
Before conducting a required performance test you must develop a site-specific fuel monitoring
plan. You do not have to submit the plan to the EPA Administrator or delegated authority unless
you intend to use an analytical method other than those required by Table 6 of the rule. You must
keep a copy of the plan as a record.
The site-specific fuel monitoring plan must include:
• Identification of all fuel types anticipated to be burned
• Notification of whether you or a fuel supplier will be conducting the fuel analysis
• A detail description of the sample location and procedures for collecting and preparing
the composite samples, if different from the procedures listed in the rule.
• Analytical methods and minimum detection levels to be used.
3.5.6 Develop and Follow an Implementation Plan for Emission Averaging
(§63.7522)
If you choose to demonstrate compliance by using emission averaging, you must develop an
implementation plan for emission averaging. You do not have to submit the plan to the EPA
Administrator or delegated authority unless it is requested. You must keep a copy of the plan as a
record.
The implementation plan must include:
• Identification of all existing boilers and process heaters in the averaging group, including
the applicable HAP emission levels and the control technologies installed as of January
31, 2013
• Date on which emission averaging is to commence
• The process parameter that will be monitored for each averaging group
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
• The specific control technology or pollution prevention measure to be used for each
boiler or process heater in the averaging group
• The test plan for measurement of emissions.
3.5.7 Conduct Initial and Annual Performance Tests
You must conduct an initial performance test to demonstrate initial compliance and to establish
operating parameters that you will follow until the next performance test. Conduct subsequent
performance tests every year (at least every 13 months)5.
Conduct all performance tests according to the requirements and methods in Table 5 of subpart
DDDDD, which specifies test methods for selecting sampling ports, determining stack gas
velocity and flow rate, determining O2 content, measuring moisture content, and measuring
emissions. You must demonstrate initial compliance and establish your operating limits based on
the performance stack tests.
Conduct performance stack tests at the typical operating conditions, while burning the type of
fuel or mixture of fuels that have the highest emissions potential for each regulated pollutant.
You must conduct a fuel analysis for each type of fuel burned in your boiler to determine the
highest emissions potential for each regulated pollutant. (See Section 3.5.6 of this guide.) Units
that use a supplemental fuel only for startup, unit shutdown, and transient flame stability
purposes still qualify as units that burn a single type of fuel, and the supplemental fuel is not
subject to the fuel analysis requirements
You may need to conduct more than one performance stack test This is because the requirement
is to test at the representative operating load conditions while burning the type of fuel or mixture
of fuels that have the highest emissions potential, for each regulated pollutant. Follow the
requirements in the General Provisions, which include:
• Completing a test method performance audit during the performance test. (The
performance audits consist of blind audit samples, supplied by an accredited audit sample
provider and analyzed during the performance test, in order to provide a measure of test
data bias.)
• Providing testing facilities that are adequate and safe to conduct stack testing.
• Conducting tests under representative conditions.
5 See §63.7515(b), if performance tests for a given pollutant for at least 2 consecutive years show emissions are at or
below 75 percent of the emission limit for the pollutant, and if there are no changes in the operation or control
equipment, may conduct performance tests for the pollutant every third year. Each such performance test must be
conducted no more than 37 months after the previous performance test. If the performance test shows that emissions
exceeded the emission limit or 75 percent of the emission limit, you must conduct annual performance tests for that
pollutant until all performance tests over a consecutive 2-year period meet the required level (at or below 75 percent
of the emission limit).
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
• Requesting to use an alternative test method, if desired.
In addition, you must follow these requirements:
• Conduct a minimum of three separate test runs for each performance stack test.
• Use EPA Method 19 (Appendix A-7 of part 60) to convert the measured particulate
matter and mercury concentrations that result from the initial performance test into
pounds per million Btu heat input emission rates.
3.5.8 Conduct Initial and Subsequent Fuel Analysis for Each Type of Fuel
Units demonstrating compliance with the Hg, HC1, or TSM emission limit through stack testing
must conduct an initial fuel analysis for each type of fuel burned in your boiler.
• If you burn more than one fuel type, you must conduct a fuel analysis to determine the
fuel type, or mixture, that would result in the maximum emission rates of Hg, HC1, or
TSM using the procedures in Table 6 of subpart DDDDD and §63.7521.
• If you plan to burn a new type of fuel or fuel mixture, you must conduct a fuel analysis
before burning the new fuel or mixture in your boiler. Recalculate the Hg, HC1, or TSM
emission rate according to §63.7521 and Equation 15 of subpart DDDDD.
- The resulting Hg, HC1, or TSM emission rate for the new type of fuel or fuel mixture
must be less than the applicable emission limit.
- If the pollutant concentration for the new fuel type or mixture is higher than for the
fuel used during the previous performance test, then you must conduct a new
performance test within 60 days of burning the new fuel type or mixture.
¦ Boilers or process heaters that burn a single type of fuel are exempted from the
requirement to conduct a fuel analysis.
¦ Boilers or process heaters that use a supplemental fuel only for startup, unit
shutdown, and transient flame stability purposes still qualify as affected boilers or
process heaters that burn a single fuel type, and the supplemental fuel is not
subject to the fuel analysis requirements.
As an alternative to stack testing for Hg, HC1, or TSM, you can demonstrate compliance using
fuel analysis. To use this alternative, you must:
• Demonstrate that the calculated emission rate according to §63.7521(e) and Equation 15
of subpart DDDDD is less than the Hg, HC1, or TSM emission limit.
• Conduct a fuel analysis each month for each type of fuel burned, reduce the data to a 12-
month rolling average, and maintain the 12-month rolling average at or below the
emission limit.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
• Conduct a fuel analysis before burning a new type of fuel or mixture in your boiler.
Recalculate the Hg, HC1, or TSM emission rate according to §63.7521(e) and Equation
15 of subpart DDDDD. The resulting Hg, HC1, or TSM emission rate for the new type of
fuel or fuel mixture must be less than the applicable emission limit.
To complete each fuel analysis, follow the procedures in §63.7521 and the methods in Table 6 of
subpart DDDDD.
• At a minimum, you must obtain three composite fuel samples for each fuel type
according to the procedures in Table 6 to subpart DDDDD. Each composite sample must
consist of a minimum of three samples collected at approximately equal intervals during
a two-hour period.
• Determine the concentration of Hg, chlorine, or TSM in the fuel in units of pounds per
million Btu of each composite sample for each fuel type according to the procedures in
Table 6 to subpart DDDDD.
3.5.9 Establish Operating Limits during the Performance Test
During the performance test, you must establish operating limits for your air pollution control
device. Table 7 of subpart DDDDD specifies how to establish operating parameters.
Wet Scrubber:
• Establish the minimum (lowest hourly average measured) liquid flow rate and pressure
drop as your operating limits during the three-run performance stack test. If you conduct
multiple performance stack tests, you must set the minimum liquid flow rate and pressure
drop operating limits at the highest minimum values established during the performance
stack tests.
Electrostatic Precipitator Operated with a Wet Scrubber:
• Establish the minimum (lowest hourly average measured) total secondary electric power
input determined from secondary voltage and secondary current.
Activated Carbon Injection:
• Establish the minimum activated carbon injection rate, which is the load fraction
multiplied by the lowest hourly average activated carbon injection rate measured during
the most recent performance test demonstrating compliance with the applicable emission
limit.
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Sorbent Injection:
• Establish the minimum sorbent injection rate, which is:
1) The load fraction multiplied by the lowest hourly average sorbent injection rate
for each sorbent measured during the most recent performance test demonstrating
compliance with the applicable emission limits; or
2) For fluidized bed combustion, the lowest average ratio of sorbent to sulfur
measured during the most recent performance test.
Boilers with Fabric Filters That Demonstrate Continuous Compliance through
Bag Leak Detection:
• Install, maintain, calibrate and operate the bag leak detection system.
• 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.
Oxygen:
• Establish a minimum (lowest hourly average measured) oxygen level.
Operating Load:
• Establish a maximum (110% of highest hourly average measured) operating load.
3.5.10 Collect Data to Demonstrate Continuous Compliance with the Emission
Limits
You must demonstrate continuous compliance with the emission limits and operating limits by
continuously monitoring your operating parameters according to the methods in Table 8 of
subpart DDDDD.
Opacity:
• Collect opacity data.
• Calculate 6-minute averages.
• Maintain opacity at 10 percent or less on a daily block average basis.
Fabric Filter Bag Leak Detection:
• Install, maintain, calibrate and operate the bag leak detection system.
• 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.
• Initiate corrective action within 1 hour of alarm sounding. Keep records of corrective
action.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Wet Scrubber Pressure Drop and Liquid Flow Rate:
• Collect pressure drop and liquid flow rate CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or above the operating limits from the performance
test.
Wet Scrubber Pressure pH:
• Collect pH CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or above the operating limits from the performance
test.
Dry Scrubber Sorbent or Carbon Injection Rate:
• Collect injection rate CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or above the operating limits from the performance
test.
ESP Total Secondary Electric Power Input:
• Collect total secondary electric power input CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or above the operating limits from the performance
test.
Oxygen Content:
• Collect the exhaust oxygen content CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or above the operating limits from the performance
test.
Operating Load:
• Collect the operating load or steam generation CMS data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or below the operating limits from the performance
test.
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Fuel Analysis:
• Collect monthly fuel analyses.
• Calculate 12-month rolling averages.
• Maintain 12-month rolling average at or
below the applicable emission limit.
PM Continuous Parameter Monitoring
System (CPMS):
• Collect the PM CPMS output data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or below
the operating limits from the performance
test.
Sulfur Dioxide (SO2) CEMS:
• Collect the SO2 CEMS output data.
• Calculate 30-day rolling averages.
• Maintain 30-day rolling average at or below
the operating limits from the performance
test.
You must operate the monitoring system(s) and
collect data at all times while the boiler or process
heater is operating. Use all the data collected in
assessing the operation of the control device and
associated control system. However, you may not use data to demonstrate compliance recorded
during:
• Startup and shutdown
• Monitoring system malfunctions or out-of-control periods (see definitions in box)
• Repairs associated with monitoring system malfunctions or out-of-control periods
• Required monitoring system quality assurance or quality control activities, including
calibration checks and required zero and span adjustments
You must make monitoring system repairs due to monitoring system malfunctions or out-of-
control periods and return the monitoring system to operation as quickly as possible. Failure to
collect required data is a deviation of the monitoring requirements. (See definition of deviation at
§63.7575.)
Out of Control Periods
A CMS is out of control if:
A. The zero (low-level), mid-level (if
applicable), or high-level calibration
drift (CD) exceeds two times the CD
specification in the applicable
performance specification or relevant
standard; or
B. The CMS fails a performance test audit
(e.g., cylinder gas audit), relative
accuracy audit, relative accuracy test
audit, or linearity test audit; or
C. The COMS CD exceeds two times the
limit in the applicable performance
specification in the relevant standard.
Malfunction
A monitoring system malfunction is any
sudden, infrequent, not reasonably
preventable failure of the monitoring
system to provide valid data. Monitoring
system failures that are caused by poor
maintenance or careless operation are not
malfunctions.
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3.5.11 Conduct Performance Evaluations of Your Continuous Monitoring
System(s)
CO limit:
• If your boiler has a CO limit, you must install, operate, and maintain a continuous oxygen
monitor at the outlet of the boiler, OR
• If you choose to comply with the alternative CO CEMS emission standard, you must
install, certify, operate, and maintain a CO CEMS and an oxygen analyzer according to
the procedures under Performance Specification 4, 4A, or 4B at 40 CFR part 60,
Appendix B.
PM CPMS:
• If your boiler or process heater is in the unit designed to burn coal/solid fossil fuel
subcategory or the unit designed to burn heavy liquid subcategory and has an average
annual heat input rate greater than 250 MMBtu per hour from solid fossil fuel and/or
heavy liquid, and you demonstrate compliance with the PM limit instead of the
alternative TSM limit, you must install, certify, maintain, and operate a PM CPMS
according to the procedures in your approved site-specific monitoring plan and the
requirements in §63.7525(b).
Opacity limit:
• If you choose to comply with an opacity limit in lieu of operating parameters for an ESP
or fabric filter, you must install, operate, certify, and maintain the COMS according to the
Performance Specification lat 40 CFR part 60, appendix B.
Fabric filter:
• If you use a fabric filter to comply with an emission limit, then you must install, calibrate,
maintain, and continuously operate the bag leak detection system, unless you choose to
comply with an opacity limit. See §63.7525(j).
All other CMS:
• If you have an operating limit that requires a continuous monitoring system (CMS), you
must install, operate, and maintain the CMS.
3.6 Task 4: Keep Records - What Records Must I Keep and for How Long?
See Task 1 for information on the initial Notification of Applicability and an initial Notification
of Compliance Status. This section addresses the remaining recordkeeping requirements.
3.6.1 General Requirements for Records and Certifications
You must keep a copy of each notification and report prepared or submitted under this rule. You
must also keep all documentation supporting any Initial Notifications or Notifications of
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Compliance Status. Please read sections 3.6.2 and 3.6.3 for details on the records required for
your boiler or process heater, based on whether work practices or emissions limits apply.
Your records must be in a form suitable and readily available for review. You must keep each
record for 5 years after the date of each recorded action. You must keep each record on site for at
least 2 years after the date of each recorded action. For the remaining 3 of the 5 years, the
records may be kept off site.
In general, you must keep copies of:
• Every notification or report, and all supporting documentation
• For operating units that combust non-hazardous secondary material, records documenting
that the material is listed as a non-waste.
• Records of all monitoring data and calculated averages for applicable operating limits,
such as opacity, pressure drop, pH, and operating load, to show continuous compliance
with each emission limit and operating limit.
• Records of monthly fuel use by each boiler or process heater, including the type(s) of fuel
and amount(s) used.
• Records of the occurrence and duration of each malfunction of the boiler or process
heater, or of the associated air pollution control and monitoring equipment
• Records of actions taken during periods of malfunction to minimize emissions, including
corrective actions to restore the malfunctioning boiler, air pollution control, or
monitoring equipment to its normal or usual manner of operation
Compliance Certification Report
If your boiler or process heater is subject to emission limits you must submit, by July 31 and
January 31 of each year, a semiannual Compliance Certification Report for the previous
semiannual reporting period (January 1 through June 30 or July 1 through December 31).
The report must contain:
1. The company name and address.
2. Process unit information, emissions limitations, and operating parameter limitations.
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3. If you use a CMS, including CEMS, COMS, or CPMS, the monitoring equipment
manufacture^s) and model numbers and the date of the last certification or audit.
4. The total fuel use by each individual boiler or process heater subject to an emission limit
within the reporting period, including a description of the fuel.
5. If conducting performance tests every 3 years, the date of the last 2 performance tests and a
statement if there have been any operational changes that could increase emissions.
6. A statement indicating that you burned no new types of fuel in any boiler or process heater
subject to an emission limit. Or, if did burn a new type of fuel and are subject to emission
limits, you must submit the calculation of chlorine, mercury, or TSM input that demonstrates
that your source is still within its maximum chlorine, mercury, or TSM input level
established during the previous performance testing (for sources that demonstrate compliance
through performance testing). Or you must submit the calculation of HC1. Mercury, or TSM
emission rate that demonstrates that your source is still meeting the emission limit for HC1,
mercury, or TSM emissions (for boilers or process heaters that demonstrate compliance
through fuel analysis).
7. A summary of any monthly fuel analyses conducted to demonstrate compliance for
individual boilers or process heaters subject to emission limits.
8. If there are no deviations from any emission limits or operating limits that apply to you, a
statement that there were no deviations from the emission limits or operating limits during
the reporting period.
9. If there were no deviations from the monitoring requirements, a statement that there were no
deviations and no periods during which the CMS were out of control during the reporting
period.
10. The date of the most recent tune-up for each unit subject to the requirement to conduct an
annual, biennial, or 5-year tune-up. Include the date of the most recent burner inspection if it
was not done annually, biennially, or on a 5-year period and was delayed until the next
scheduled or unscheduled unit shutdown.
11. If you demonstrate compliance by emission averaging, a certification that the emission level
achieved or the control technology employed is no less stringent than the level or control
technology contained in the notification of compliance status.
12. All of the calculated 30-day rolling average values for each reporting period based on the
daily CEMS and CPMS data.
13. A statement by a responsible official certifying the truth, accuracy, completeness of the
certification, and a statement of whether the source has complied with all the relevant
standards and requirements of the rule. The statement needs to also supply the official's
name, title, phone number, e-mail address, and signature.
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14. For any deviations from the applicable requirements during the reporting period, include
each instance in which you did not meet an emission limit and operating limit. Include a
description of deviations, the time periods during which the deviations occurred, and the
corrective actions taken.
3.6.2 Work Practice Standards Recordkeeping
Tune-up:
• For Initial Tune-up. You must conduct a performance tune-up and you must submit a
signed statement in the Notification of Compliance Status report that indicates that you
conducted an initial tune-up of the boiler.
• For Subsequent Tune-ups:
o For units that are subject only to a requirement to conduct an annual, biennial, or
5-year tune-up, respectively, and not subject to emission limits or operating limits,
you may submit only an annual, biennial, or 5-year compliance report, as
applicable, instead of a semiannual compliance report,
o For units subject to emission limits or operating limits and must conduct a
performance tune-up, you must include in the semiannual compliance report the
date of the most recent tune-up for each unit subject to the requirement to conduct
an annual, biennial, or 5-year tune-up, respectively. Include the date of the most
recent burner inspection if it was not done annually, biennially, or on a 5-year
period and was delayed until the next scheduled or unscheduled unit shutdown.
• For all tune-ups, you must keep records of the dates and procedures of each tune-up, and
the fuel used. You should begin keeping fuel records for at least 12 months prior to the
scheduled tune-up. The record must be kept on-site and submitted to the delegated
authority if requested. You may use the example form to document the tune-up, keep
records, and meet the reporting requirement.
Example forms can be found at http://www.epa.gov/ttn/atw/boiler/boilerpg.html under
"Implementation Information."
Energy Assessment:
• Submit a signed certification in the Notification of Compliance Status report that an
energy assessment of the boiler(s) and/or process heater(s) and its energy use systems
was completed.
Startup and Shutdown:
• Maintain records of the calendar date, time, occurrence and duration of each startup and
shutdown.
• Must maintain records of the type(s) and amount(s) of fuels used during each startup and
shutdown.
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3.6.3 Emission Limits Recordkeeping
You will need to keep records related to emission limits, test plans, monitoring plans/data,
operating limits and fuel type/amount.
Fuel Analysis:
• Keep a copy of all calculations and supporting documentation to demonstrate compliance
with the mercury, HC1, and/or TSM emission limits. Supporting documentation should
include results of any fuel analyses. You can use the results from one fuel analysis for
multiple units, provided they are all burning the same fuel type.
• Maintain records of the type and amount of all fuels burned in each boiler and process
heater during the annual reporting period to demonstrate that all fuel types and mixtures
of fuels burned would result in lower emissions of mercury, HC1, and/or TSM than the
applicable emission limit (if you demonstrate compliance through fuel analysis).
Site-specific Test Plan:
• Prepare the site-specific test plan before conducting a required performance test (see
specific plan requirements in Section 3.5.7).
• Keep a copy of the site-specific test plan as a record.
• Submit the site-specific test plan if requested by the EPA
or a delegated authority.
Site-specific Monitoring Plan:
• Prepare the site-specific monitoring plan at least 60 days
before your initial performance evaluation of your CMS
(see specific plan requirements in Section 3.5.4).
Inspection and Monitoring Data:
• Keep records of all inspection and monitoring data for
each required inspection or monitoring event including:
o Person conducting the monitoring
o Technique or method used
o Operating conditions during the activity
o Results, including the date, time, and duration of the period from the time the
monitoring indicated a problem to the time that monitoring indicated proper
operation
o Maintenance or corrective action taken (if applicable)
[ NOTE: A site-specific
( monitoring plan is not required
j if you have existing monitoring
j plans for CEMS and COMS
J prepared under Appendix B to
| Part 60 that meet all
t monitoring, installation,
j operation, and maintenance
j requirements.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Fabric Filter:
For boilers or process heaters that demonstrate compliance with a fabric filter and bag leak
detection system, include:
• Records of the bag leak detection system output
• Records of bag leak detection system adjustments
• The date and time of all bag leak detection system alarms, date and time you initiated and
completed corrective action, brief description of corrective action taken
• The percent of the operating time during each 6-month period that the alarm sounds
Fuel Type and Amount:
All boilers and process heaters should keep records documenting the fuel type(s) used monthly
by each boiler or process heater, including:
• The total fuel usage amount with units of measure
• A description of the fuel, including if the fuel has received a non-waste determination by
you or EPA, and all records that show how the legitimacy criteria are met for that
determination
Emission Averaging:
• If you choose to average emissions consistent with §63.7522, you must keep a copy of
the emission averaging implementation plan required in §63.7522(g), all calculations
required under §63.7522, including monthly records of heat input or steam generation, as
applicable, and monitoring records consistent with §63.7541.
Efficiency Credits:
• If you choose to use efficiency credits from energy conservation measures to demonstrate
compliance according to § 63.7533, you must keep a copy of the Implementation Plan
required in §63.7533(d) and copies of all data and calculations used to establish credits
according to §63.7533(b), (c), and (f).
Limited-use Units:
• Must keep a copy of the federally enforceable permit that limits the annual capacity
factor to less than or equal to 10 percent and fuel use records for the days the boiler or
process heater was operating.
For boilers that demonstrate compliance with a mercury, HC1, or TSM emission limit through
stack testing, 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
result in lower fuel input of mercury, HC1, and/or TSM than the maximum values
calculated during the last performance stack test.
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3.7 Task 5: Submit Other Notifications and Reports
See Task 1 for information on the initial Notification of Applicability and an initial Notification
of Compliance Status. This section addresses the remaining reporting and notification
requirements.
3.7.1 Commencing or Recommencing Combustion of Solid Waste (§63.7545(g)):
If you intend to commence or recommence combustion of solid waste, you must provide 30 days
prior notice to EPA or the delegated authority. The notification must identify:
• The name of the owner or operator of the affected source, the location of the source, the
boiler(s) that will commence burning solid waste, and the date of the notice
• The currently applicable subcategory under this subpart
• The date on which you became subject to the currently applicable emission limits
• The date upon which you will commence or recommence combusting solid waste
3.7.2 Switching Fuels (§63.7545(h)):
If you have switched fuels or made a physical change to the boiler and this resulted in the
applicability of a different subcategory, you must provide notice within 30 days of the
switch/change. The notification must identify:
• The name of the owner or operator of the affected source, the location of the source, the
boiler(s) and process heater(s) that have switched fuels, or were physically changed, and
the date of the notice.
• The currently applicable subcategory under this subpart
• The date on which you became subject to the currently applicable standards
• The date upon which you the fuel switch or physical change occurred.
If you own or operate an industrial, commercial, or institutional boiler or process heater and
would be subject to this subpart except for the exemption for commercial and industrial solid
waste incineration units covered by 40 CFR part 60, subpart CCCC or subpart DDDD, and you
cease combusting solid waste, then you must be in compliance with this subpart on the effective
date of the waste to fuel switch.
3.7.3 Notification of Affirmative Defense:
If your facility experiences an exceedance of your emission limit(s) during a malfunction, you
must:
• Submit a written report to the Administrator with all necessary supporting
documentation, that you have met the requirements set forth in § 63.7500. This
affirmative defense report must be included in the first compliance, deviation or excess
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emission report otherwise required after the initial occurrence of the violation of the
relevant standard (which may be the end of any applicable averaging period). If the
report is due less than 45 days after the initial occurrence of the violation, your
affirmative defense report may be included in the second report due after the initial
occurrence of the violation of the relevant standard.
• Prepare a written root-cause analysis, showing how you determined, corrected, and
eliminated the primary causes of the malfunction and the violation resulting from the
malfunction. This analysis must also include, using your best monitoring methods and
engineering judgment, the amount of any emissions that were the result of the
malfunction.
3.7.4 Tune-up and Energy Assessment Reporting:
You do not need to submit the results of your energy assessment or tune-up. These items will be
kept as records and only submitted if requested by your delegated authority. Section 3.6.2
summarizes the records that must be kept for work practice standards.
3.7.5 Stack Test Performance Data Reporting:
If your boiler or process heater is subject to stack testing, you must:
• Submit the results of the performance tests, including any fuel analyses and compliance
reports, within 60 days of completing each performance test electronically to EPA's
WebFIRE database by using the Compliance and Emissions Data Reporting Interface
(CEDRI) which is accessed through the EPA's Central Data Exchange (CDX)
(www.epa. sov/cdx).
• Submit performance test data in the format generated through the EPA's Electronic
Reporting Tool (ERT) (see http://www. epa. gov/ttn/chief/ert/index. html). Only data
collected using test methods on the ERT Web site must be submitted electronically to
WebFIRE.
• If you wish to claim that some of the information being submitted for performance tests
is confidential business information (CBI), you must submit a complete ERT file
including information claimed to be CBI on a compact disk or other commonly used
electronic storage media (including, but not limited to, flash drives) to the EPA. The
electronic media must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE
CBI Office, Attention: WebFIRE Administrator, MD C404-02, 4930 Old Page Rd.,
Durham, NC 27703. The same ERT file with the CBI omitted must be submitted to the
EPA via CDX.
• For any performance test conducted using test methods that are not listed on the ERT
Web site, you must submit the results on paper to the Administrator.
• If your boiler experiences any deviations, you must submit an Annual Compliance
Report. See Section 3.6 for details of the annual compliance report.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
4.0 OTHER INFORMATION
4.1 Benefits and Costs
EPA estimates that there are approximately 14,100
existing area source boilers at 1,700 facilities in the
United States and that approximately 1,800 new
boilers and process heaters will be installed over the
next 3 years.
EPA estimates that the value of the benefits from
reduced exposure to fine particles is $25 billion to
$61 billion in the year 2016. EPA did not estimate
monetary benefits from reducing exposure to air
toxics or other air pollutants, ecosystem effects, or
visibility impairment.
The final rule will reduce emissions of a number of
toxic air pollutants including mercury, metals, and
organic air toxics, including dioxins. Toxic air
pollutants, also known as hazardous air pollutants
(HAPs) or air toxics, include pollutants that are of
particular concern for children. For example,
mercury and lead can adversely affect developing brains - including effects on IQ, learning, and
memory. Cadmium, dioxin, furans, formaldehyde and hydrochloric acid, also reduced by this
rule, can cause cancer or other adverse health effects in adults and children. Mercury, lead,
dioxin, and furans can also build up in the environment, causing serious environmental effects
and harm to the food chain.
Furthermore, the boiler tune-ups required by this regulation can save facilities energy-related
costs, and the energy audit portion of the regulation will identify additional energy and cost
savings.
Additional efficiencies can be achieved if a facility chooses to comply through the installation of
more advanced energy saving measures identified in the energy assessment. The Department of
Energy plans to provide information to affected sources on financial incentives available at the
local, state, utility and federal level to assist them in completing a boiler tune-up and/or energy
assessment (see link in "Other Governmental Support" below).
4.2 Compliance Assistance Resources
EPA believes that through awareness, education and reasonable options, both public and private
members of the regulated community will be proactive in voluntary efforts to comply with
pollution control regulations. Compliance assistance providers help regulated communities and
businesses understand and comply with environmental laws through one-to-one counseling,
Estimated Compliance Costs
Based on data collected to support the
regulatory impact analysis, EPA estimates
the following costs:
>Tune-up: $200 to $8,000 per boiler, per
tune-up, depending on size of boiler and
any necessary adjustments.
> Energy Assessment: $3,500 to $75,000
depending on the size and number of
energy use systems at the facility
>For a 50 MMBtu/hr coal boiler:
o Fabric Filter: $2.1 million total
capital expenditures and $563,000
in annual operating and
maintenance costs
o Testing for CO and Hg: $11,000
(testing required every 3 years)
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
online resource centers, fact sheets, guides, and training. Assistance providers include EPA
regional office staff; state, local and tribal governments; federal and state small business and
pollution prevention technical assistance extension agents, consultants, and trade associations.
Find out what laws apply to you, what you need to do to comply, and tools and resources that
can help you and your constituents comply with environmental regulations by visiting the
following websites:
EPA Compliance Assistance: http://www.epa.gov/compliance/assistance/business.html
EPA National Compliance Assistance Centers Boiler / Combustion Web Portal:
www, combustionportal. org
EPA National Compliance Assistance Centers: http://www.assistancecenters.net/
State-by-state Resource Locator: http://www.envcap.org/statetools/
EPA Small Business Environmental Assistance: http://www.smallbiz-enviroweb.org/
EPA Small Business Gateway: http://www.epa.gov/smallbusiness/
EPA Environmental Regulations and Laws: http://www.epa.gov/smallbusiness/regs.htm
EPA Pollutants and Sources: http://www.epa.gov/airtoxics/pollsour.html
EPA Air Toxics Website: http://www.epa.gov/ttn/atw/
Emissions Standards for Boilers and Process Heaters and Commercial / Industrial Solid Waste
Incinerators http ://www. epa. gov/airqualitv/combustion/actions .html
Preferred and Alternative Methods for Estimating Air Emissions from Boilers:
http://www.epa.gov/ttn/chief/eiip/techreport/volume02/ii02.pdf
EPA Asbestos and Small Business Ombudsman: http://www.epa.gov/sbo/
EPA Small Business Compliance and Enforcement:
http://www.epa.gov/compliance/incentives/smallbusiness/
EPA Compliance Incentives and Auditing:
http://www.epa.gov/oecaerth/incentives/auditing/auditpolicv.html
4.3 Other Governmental Support
EPA is working with the U.S. Department of Energy (DOE) and the U.S. Department of
Agriculture (USDA) to provide technical assistance that will help boilers burn cleaner and more
efficiently.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
DOE will provide support through their regional Clean Energy Application Centers to large
sources that burn coal and oil. Along with information on financial incentives, funding, and
financing opportunities, DOE will supply site-specific information on clean energy compliance
strategies, including cost and payback information. Large sources may also have the opportunity
to develop energy efficient compliance strategies, such as combined heat and power. Assistance
resources that can provide help to facilities that need it. Initial information is at
http ://wwwl. eere. energy, gov/industry/states/.
USD A will reach out to small sources that burn biomass through a variety of networks, to help
owners and operators understand the standards and what is required to be in compliance. The
outreach will outline the benefits of implementing the rule for owners and their neighbors, and
provide information on work practice standards.
4.4 What Other Resources are Available?
State and local contacts can be found at the National Association of Clean Air Agencies web site
(http://www.4cleanair.org/). at the EPA Regional offices
(http://www.epa.gov/epahome/wherevoulive.htm). or under the EPA State, Local, Tribal and
Federal Partnerships (http://www.epa.gov/ttn/atw/stprogs.html). State Small Business Assistance
Program contacts can be found at http://www. smallbiz-enviroweb.org/.
4.5 For More Information
The full text of the Federal Register containing the rule and additional information are available
online at: http://www.epa.gov/ttn/atw/boiler/boilerpg.html.
A link to the current Boiler MACT and General Provisions in the Electronic Code of Federal
Regulations (e-CFR) is available online.
Other background information is also available at
http://www.epa.gov/airqualitv/combustion/actions.html and in the rulemaking docket (Docket
ID: EPA-HQ-OAR-2002-0058) either electronically at http://www.regulations.gov. EPA's
electronic public docket and comment system, or in hardcopy at the EPA Docket Center's Public
Reading Room.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Appendix A
Summary of Requirements for 40 CFR Part 63, Subpart DDDDD
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Summary of Requirements for 40 CFR Part 63 Subpart DDDDD:
NESHAP for Major Sources: Industrial, Commercial, and Institutional Boilers and Process
Heaters
Task 1: Submit Initial Notifications
TASK
By When?
Applicable to ..
Comment
Submit Initial
Notification of
Applicability
Submit by 5/31/2013.
Existing Units
§63.7545(b)
No later than 15 days
after date of actual
startup
New Units
§63.7545(c)
Submit Notification of
Compliance Status
Submit within 60 days
following completion of
all initial compliance
demonstrations
ALL
§63.7545(e)
Task 2: Comply with Work Practice Standards
TASK
By When?
Applicable to...
Comment
Conduct
Tune-up
Initial
1/31/2016
Existing Units
Subsequent
Annually, no later
than 13 months
after previous tune-
upa
Existing and new units without a
continuous oxygen trim system
and with heat input capacity of
10 MMBtu/hr or greater.
Item 3 of
Table 3 of
subpart DDDDD
Biennially, no later
than 25 months
after previous tune-
upa
Existing and new units without a
continuous oxygen trim system
and with heat input capacity of
less than 10 MMBtu/hr in the
heavy liquid or solid fuel
subcategories; or a unit with
heat input capacity of less than
10 MMBtu/hr but greater than 5
MMBtu/hr, in any of the
following subcategories: Gas 1;
Gas 2 (other); or light liquid.
Item 2 of
Table 3 of
subpart DDDDD
Every 5 years, no
later than 61
months after
Existing and new units with a
continuous oxygen
trim system, or a heat
Item 1 of
Table 3 of
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
previous tune-upa
input capacity of less than or
equal to 5 MMBtu/hr in any of
the following subcategories: Gas
1; Gas 2 (other); or light liquid,
or a limited-use unit.
subpart DDDDD
Conduct One-Time Energy
Assessment
1/31/2016
Existing Units Only
Item 4 of
Table 3 of
subpart DDDDD
Comply with
Startup/Shutdown
Procedures
Beginning
1/31/2016
Units subject to emission limits
Item 5 and 6 of
Table 3 of
subpart DDDDD
a Note: For new sources, t
ie first annual, biennial, or 5-year tune-up must be no
ater than 13
months, 25 months, or 61 months, respectively, after January 31, 2013 or the initial startup of the
new or reconstructed affected source, whichever is later.
Task 3: Meet Emission Limits
TASK
For This Pollutant
Initial Compliance
Continuous Compliance
PM (or TSM), mercury,
HCL
Existing Units: Conduct
performance (stack) test by
7/29/2016
New Units: Within 180 davs
of date of actual startup
Annually, except that if performance tests
for a given pollutant for at least 2
consecutive years show emissions are at or
below 75 percent of the emission limit,
and there are no changes in the operation
or control equipment, may conduct
performance tests for the pollutant every
third year. Each such performance test
must be conducted no more than 37
months after the previous performance
test.
Establish operating limits
(Table 7 of subpart DDDDD):
Existing Units: bv 7/29/2016.
New Units: Within 180 davs
of date of actual startup
Operate monitoring systems, collect data,
and maintain operating limit (Table 8 of
subpart DDDDD).
Conduct CMS performance
evaluations:
Existing Units: bv 7/29/2016.
New Units: Within 180 days
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
of date of actual startup
OR
TSM, mercury, HCI
Conduct fuel analysis
(63.7521, Table 6 and
63.7530(c));
Existing Units: bv
7/29/2016.
New Units: Within 180
days of date of actual
startup
Conduct fuel analysis for each fuel type
burned monthly and maintain operating
limit (item 8 of Table 8 of subpart DDDDD)
CO
Conduct performance
(stack) test:
Existing Units: bv
7/29/2016
New Units: Within 180
days of date of actual
startup
Annually, except that if performance tests
for a given pollutant for at least 2
consecutive years show emissions are at or
below 75 percent of the emission limit,
and there are no changes in the operation
or control equipment, may conduct
performance tests for the pollutant every
third year. Each such performance test
must be conducted no more than 37
months after the previous performance
test.
Establish operating
limits (Table 7 of
subpart DDDDD):
Existing Units: bv
9/17/2014.
New Units: Within 180
days of date of actual
startup
Operate monitoring systems, collect data,
and maintain operating limit (Table 8 of
subpart DDDDD).
Conduct CMS
performance
evaluations:
Existing Units: bv
7/29/2016.
New Units: Within 180
days of date of actual
startup
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
OR
Alternative CO CEMS-based
Limit
Conduct CEMS
performance evaluation
(§63.7525(a)(2)):
Existing Units: bv
7/29/2016.
New Units: Within 180
days of date of actual
startup
Maintain CO emission level below or at
applicable alternative CO CEMS-based
standard (§63.7540(a)(8)(ii)).
Task 4: Recordkeeping6
TASK
Applicable to ..
Comment
Records of all submitted notifications
See §63.7555(a)(1)
Records of all submitted reports
See §63.7555(a)(1)
Records of performance tests, fuel analyses, or
other compliance demonstrations and performance
evaluations
See §63.7555(a)(2)
Records of all monitoring data and calculated
averages for applicable operating limits
to show continuous compliance with each emission
limit and operating limit that applies
See §63.7555(c)
Records of monthly fuel use, including the type(s)
of fuel and amount(s) used.
For each boiler or
process heater subject to
an emission limit
See 63.7555(d)(1)
Record that documents how the secondary material
meets each of the legitimacy criteria under
§241.3(d)(1), or
if it has been processed from a discarded
nonhazardous secondary material, must
keep records as to how the operations that
produced the fuel satisfy the definition of
For each unit that
combust non-hazardous
secondary materials that
have been
determined not to be
solid waste
See §63.7555(d)(2).
6 Records must be in a form suitable and readily available for expeditious review. Each record must be kept for 5 years
following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Each record must be kept
on site, or they must be accessible from on site (for example, through a computer network), for at least 2 years after the date of
each occurrence, measurement, maintenance, corrective action, report, or record. Records can be kept off site for the remaining 3
years.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
processing in § 241.2, or
if the fuel received a nonwaste determination
pursuant to the petition process submitted under
§ 241.3(c), must keep a record that documents how
the fuel satisfies the requirements of the petition
process.
Records documenting that the material is listed as a
non-waste under § 241.4(a) of this
chapter
For operating units that
combust non-hazardous
secondary
materials as fuel
Units exempt from
the incinerator
standards under
section 129(g)(1) of
the Clean Air Act
because they are
qualifying facilities
burning a
homogeneous waste
stream do not need
to maintain the
records
Copy of the federally enforceable permit that limits
the annual capacity factor to less than or equal to
10 percent and fuel use records for the days the
boiler or process heater was operating.
For units in the limited-
use subcategory,
Copy of all calculations and supporting
documentation of maximum chlorine, mercury,
and/or TSM fuel input, that were done to
demonstrate continuous compliance with the HCI,
mercury, and/or TSM emission limits, respectively.
For sources that
demonstrate compliance
through performance
testing.
Copy of all calculations and supporting
documentation of HCI, mercury, and/or TSM
emission rates that were done to demonstrate
compliance with the HCI, mercury, and/or TSM
emission limits, respectively.
For sources that
demonstrate compliance
through fuel
analysis,
Record that documents that your emissions in the
previous stack test(s) were less than 75 percent of
the applicable emission limit, and document that
there was no change in source operations including
fuel composition and operation of air pollution
control equipment that would cause emissions of
the relevant pollutant to increase within the past
year.
For each boiler or
process heater subject to
an emission limit and, if,
consistent with
§63.7515(b), you choose
to stack test less
frequently than annually.
See §63.7555(d)(6).
Records of the occurrence and duration of each
malfunction of the boiler or process heater, or of
the associated air pollution control and monitoring
equipment.
For each boiler or
process heater subject to
an emission limit subject
to an emission limit
See §63.7555(d)(7).
Records of actions taken during periods of
malfunction to minimize emissions in accordance
with the general duty to minimize emissions,
For each boiler or
process heater subject to
an emission limit For
See §63.7555(d)(8).
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
including corrective actions to restore the
malfunctioning boiler or process heater, air
pollution control, or monitoring equipment to its
normal or usual manner of operation.
each boiler or process
heater
Records of the calendar date, time, occurrence and
duration of each startup and shutdown.
For each boiler or
process heater subject to
an emission limit.
See §63.7555(d)(10)
Records of the type(s) and amount(s) of fuels used
during each startup and shutdown.
For each boiler or
process heater subject to
an emission limit.
See §63.7555(d)(ll)
Copy of the emission averaging implementation
plan, all calculations, including monthly records of
heat input or steam generation, as applicable, and
monitoring records
If you elect to average
emissions
See §63.7555(e)
Copy of the Efficiency Credit
Implementation Plan and copies of all data and
calculations used to establish credits
If you elect to use
efficiency credits from
energy conservation
measures to
demonstrate compliance
See §63.7555(f)
Monthly records (or at the frequency required by §
63.7540(c)) of the calculations and results of the
fuel
specification for mercury
If you elected to
demonstrate that the
unit meets the
specification for mercury
for the unit designed to
burn gas 1 subcategory
See §63.7555(g)
Records of the total hours per calendar year that
alternative fuel is burned and the total hours per
calendar year that the unit operated during periods
of gas curtailment or gas supply emergencies.
A unit in the Gas 1
subcategory and you use
an alternative fuel other
than natural gas, refinery
gas, gaseous fuel subject
to another subpart under
this part, other gas 1 fuel,
or gaseous fuel subject to
another subpart of this
part or part 60, 61, or 65,
See §63.7555(h)
Energy Assessment Report
See §63.11214(c)
Site-specific test plan
Annual compliance certification report
Site-specific monitoring plan
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Task 5: Submit Other Notifications and Reports7
TASK
By When?
Applicable to ..
Comment
Notification that you have
switched fuels or made a
physical change to the boiler
and the fuel switch or physical
change resulted in the
applicability of a different
subcategory
Within 30 days of the
switch/change.
See §63.7545(h)
First compliance report
Submitted 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 each boiler
or process heater.
See §63.7550(b)
Subsequent compliance
report
Submitted no later than July
31 or January 31,
whichever date is the first
date following the end of the
semiannual reporting period.8
Annual, biennial, or 5-year
compliance report, instead of a
semiannual compliance report.
The first annual, biennial, or 5-
year compliance report must
be postmarked or submitted
no later than
January 31 following the end
of the first calendar half after
the compliance date that is
specified for
each boiler or process heater.
Subseauent annual, biennial,
and 5-year compliance reports
must be postmarked or
submitted no later than
January 31.
For units that
are subject only
to a
requirement to
conduct an
annual,
biennial, or 5-
year tune-up
and not subject
to emission
limits or
operating limits
See §63.7550(b)
7
Owners or operators who claim that some of the information being submitted for performance tests is confidential business
information (CBI) must submit a complete ERT file including information claimed to be CBI on a compact disk or other
commonly used electronic storage media (including, but not limited to, flash drives) to the EPA. Hie electronic media must be
clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404-02,
4930 Old Page Rd., Durham, NC 27703. The same ERT file with the CBI omitted must be submitted to the EPA via CDX.
8 The semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through
December 31. Annual, biennial, and 5-year compliance reports must cover the applicable 1 -, 2-, or 5-year periods from
January 1 to December 31.
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Notification of intent to
commence or
recommence combustion of
solid waste,
30 days prior notice
of the date upon which you
will commence or
recommence combustion
of solid waste.
See §63.7545(g)
Affirmative defense report
Include in first periodic
compliance report
See §63.7501(b)
Site-specific monitoring plan
Upon request
If you
demonstrate
compliance
with any
applicable
emission limit
through
performance
testing and
subsequent
compliance with
operating
limits (including
the use of
CPMS), or
with a CEMS, or
CO MS
See
§63.7505(d)(1)
Submit results of performance
tests to EPA's Central Data
Exchange using the ERT:
http://www.epa.gOv/ttn/chief/e
rt/erttool.html
Within 60 days of completing
each performance test.
See
§63.7525(b)(5)(i
v)
Submit each CEMS relative
accuracy test audit to EPA's
Central Data Exchange using the
ERT
http://www.epa.g0v/ttn/chief/e
rt/erttool.html
Within 60 days of completing
audits.
See
§63.7525(b)(5)(i
v)
Site-specific fuel monitoring
plan
No later than 60 days before
the date that you intend to
conduct the
initial compliance
demonstration
If you intend to
use an
alternative
analytical
method other
than those
required by
See
63.7521(b)(1)
63.75219(g)
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Small Entity Compliance Guide For Major Source Boilers and Process Heaters
Table 6 to this
subpart
Annual tune-up report
Upon request
See
63.7540(a)(10)(v
i)
Submit a notification of
alternative fuel use
Within 48 hours of the
declaration of each period of
natural gas curtailment or
supply interruption
If you operate a
unit in the GAS 1
subcategory and
you intend to
use a fuel other
than natural
gas, refinery
gas, gaseous
fuel subject to
another subpart
of this part, part
60, 61, or 65, or
other gas 1 fuel
to fire the
affected unit
during a period
of natural gas
curtailment or
supply
interruption
See 63.7545(f)
Implementation plan for
emission averaging
Upon request
See 63.7522(g)
Efficiency credit implantation
plan
Upon request. If requested,
submit the implementation
plan for efficiency credits to
the Administrator for review
and approval no later than
180 days before the date on
which the facility intends to
demonstrate compliance
using the efficiency credit
approach
See §63.7533(d)
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