[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 2001 Edition]
[From the U.S. Government Printing Office]
[[Page i]]
40
Part 60 (Sec. 60.1 to End)
Revised as of July 1, 2001
Protection of Environment
Containing a codification of documents of general
applicability and future effect
As of July 1, 2001
With Ancillaries
Published by
Office of the Federal Register
National Archives and Records
Administration
A Special Edition of the Federal Register
[[Page ii]]
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As of July 1, 2001
Title 40, Part 60
Revised as of July 1, 2000
Is Replaced by Two Volumes
Title 40, Part 60 (Sec. 60.1 to End)
and
Title 40, Part 60 (Appendices)
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U.S. GOVERNMENT PRINTING OFFICE
WASHINGTON : 2001
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Office
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2250
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[[Page iii]]
Table of Contents
Page
Explanation................................................. v
Title 40:
Chapter I--Environmental Protection Agency 3
Finding Aids:
Material Incorporated by Reference...................... 707
Table of CFR Titles and Chapters........................ 713
Alphabetical List of Agencies Appearing in the CFR...... 731
List of CFR Sections Affected........................... 741
[[Page iv]]
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Cite this Code: CFR
To cite the regulations in
this volume use title,
part and section number.
Thus, 40 CFR 60.1 refers
to title 40, part 60,
section 1.
----------------------------
[[Page v]]
EXPLANATION
The Code of Federal Regulations is a codification of the general and
permanent rules published in the Federal Register by the Executive
departments and agencies of the Federal Government. The Code is divided
into 50 titles which represent broad areas subject to Federal
regulation. Each title is divided into chapters which usually bear the
name of the issuing agency. Each chapter is further subdivided into
parts covering specific regulatory areas.
Each volume of the Code is revised at least once each calendar year
and issued on a quarterly basis approximately as follows:
Title 1 through Title 16.................................as of January 1
Title 17 through Title 27..................................as of April 1
Title 28 through Title 41...................................as of July 1
Title 42 through Title 50................................as of October 1
The appropriate revision date is printed on the cover of each
volume.
LEGAL STATUS
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HOW TO USE THE CODE OF FEDERAL REGULATIONS
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OMB CONTROL NUMBERS
The Paperwork Reduction Act of 1980 (Pub. L. 96-511) requires
Federal agencies to display an OMB control number with their information
collection request.
[[Page vi]]
Many agencies have begun publishing numerous OMB control numbers as
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OBSOLETE PROVISIONS
Provisions that become obsolete before the revision date stated on
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of provisions in effect on a given date in the past by using the
appropriate numerical list of sections affected. For the period before
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1963, 1964-1972, or 1973-1985, published in seven separate volumes. For
the period beginning January 1, 1986, a ``List of CFR Sections
Affected'' is published at the end of each CFR volume.
INCORPORATION BY REFERENCE
What is incorporation by reference? Incorporation by reference was
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This material, like any other properly issued regulation, has the force
of law.
What is a proper incorporation by reference? The Director of the
Federal Register will approve an incorporation by reference only when
the requirements of 1 CFR part 51 are met. Some of the elements on which
approval is based are:
(a) The incorporation will substantially reduce the volume of
material published in the Federal Register.
(b) The matter incorporated is in fact available to the extent
necessary to afford fairness and uniformity in the administrative
process.
(c) The incorporating document is drafted and submitted for
publication in accordance with 1 CFR part 51.
Properly approved incorporations by reference in this volume are
listed in the Finding Aids at the end of this volume.
What if the material incorporated by reference cannot be found? If
you have any problem locating or obtaining a copy of material listed in
the Finding Aids of this volume as an approved incorporation by
reference, please contact the agency that issued the regulation
containing that incorporation. If, after contacting the agency, you find
the material is not available, please notify the Director of the Federal
Register, National Archives and Records Administration, Washington DC
20408, or call (202) 523-4534.
CFR INDEXES AND TABULAR GUIDES
A subject index to the Code of Federal Regulations is contained in a
separate volume, revised annually as of January 1, entitled CFR Index
and Finding Aids. This volume contains the Parallel Table of Statutory
Authorities and Agency Rules (Table I). A list of CFR titles, chapters,
and parts and an alphabetical list of agencies publishing in the CFR are
also included in this volume.
An index to the text of ``Title 3--The President'' is carried within
that volume.
The Federal Register Index is issued monthly in cumulative form.
This index is based on a consolidation of the ``Contents'' entries in
the daily Federal Register.
A List of CFR Sections Affected (LSA) is published monthly, keyed to
the revision dates of the 50 CFR titles.
[[Page vii]]
REPUBLICATION OF MATERIAL
There are no restrictions on the republication of material appearing
in the Code of Federal Regulations.
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For a legal interpretation or explanation of any regulation in this
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Raymond A. Mosley,
Director,
Office of the Federal Register.
July 1, 2001.
[[Page ix]]
THIS TITLE
Title 40--Protection of Environment is composed of twenty-eight
volumes. The parts in these volumes are arranged in the following order:
parts 1-49, parts 50-51, part 52 (52.01-52.1018), part 52 (52.1019-End),
parts 53-59, part 60 (60.1-End), part 60 (Appendices), parts 61-62, part
63 (63.1-63.599), part 63 (63.600-1-63.1199), part 63 (63.1200-End),
parts 64-71, parts 72-80, parts 81-85, part 86 (86.1-86.599-99) part 86
(86.600-1-End), parts 87-99, parts 100-135, parts 136-149, parts 150-
189, parts 190-259, parts 260-265, parts 266-299, parts 300-399, parts
400-424, parts 425-699, parts 700-789, and part 790 to End. The contents
of these volumes represent all current regulations codified under this
title of the CFR as of July 1, 2001.
Chapter I--Environmental Protection Agency appears in all twenty-
four volumes. A Pesticide Tolerance Commodity/Chemical Index and Crop
Grouping Commodities Index appear in parts 150-189. A Toxic Substances
Chemical--CAS Number Index appears in parts 700-789 and part 790 to End.
Redesignation Tables appear in the volumes containing parts 50-51, parts
150-189, and parts 700-789. Regulations issued by the Council on
Environmental Quality appear in the volume containing part 790 to End.
The OMB control numbers for title 40 appear in Sec. 9.1 of this chapter.
[[Page x]]
[[Page 1]]
TITLE 40--PROTECTION OF ENVIRONMENT
(This book contains part 60 (Sec. 60.1 to end))
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Part
chapter i--Environmental Protection Agency (Continued)...... 60
[[Page 3]]
CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY
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SUBCHAPTER C--AIR PROGRAMS (CONTINUED)
Part Page
60 Standards of performance for new stationary
sources................................. 5
Editorial Notes: 1. Subchapter C--Air Programs is contained in volumes
40 CFR parts 50-51, part 52.01-52.1018, part 52.1019-end, parts 53-59,
part 60 (60.1-end), part 60 (Appendices), parts 61-62, part 63 (63.1-
63.599), part 63 (63.600-63.1199), part (63.1200-End), parts 64-71,
parts 72-80, parts 81-85, part 86 (86.1-86.599-99), part 86 (86.600 to
end) and parts 87-99.
2. Nomenclature changes to chapter I appear at 65 FR 47324, 47325,
Aug. 2, 2000; 66 FR 34375, 34376, June 28, 2001.
[[Page 5]]
SUBCHAPTER C--AIR PROGRAMS (CONTINUED)
PART 60--STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Table of Contents
Subpart A--General Provisions
Sec.
60.1 Applicability.
60.2 Definitions.
60.3 Units and abbreviations.
60.4 Address.
60.5 Determination of construction or modification.
60.6 Review of plans.
60.7 Notification and record keeping.
60.8 Performance tests.
60.9 Availability of information.
60.10 State authority.
60.11 Compliance with standards and maintenance requirements.
60.12 Circumvention.
60.13 Monitoring requirements.
60.14 Modification.
60.15 Reconstruction.
60.16 Priority list.
60.17 Incorporations by reference.
60.18 General control device requirements.
60.19 General notification and reporting requirements.
Subpart B--Adoption and Submittal of State Plans for Designated
Facilities
60.20 Applicability.
60.21 Definitions.
60.22 Publication of guideline documents, emission guidelines, and
final compliance times.
60.23 Adoption and submittal of State plans; public hearings.
60.24 Emission standards and compliance schedules.
60.25 Emission inventories, source surveillance, reports.
60.26 Legal authority.
60.27 Actions by the Administrator.
60.28 Plan revisions by the State.
60.29 Plan revisions by the Administrator.
Subpart C--Emission Guidelines and Compliance Times
60.30 Scope.
60.31 Definitions.
Subpart Ca [Reserved]
Subpart Cb--Emissions Guidelines and Compliance Times for Large
Municipal Waste Combustors That Are Constructed on or Before September
20, 1994
60.30b Scope.
60.31b Definitions.
60.32b Designated facilities.
60.33b Emission guidelines for municipal waste combustor metals, acid
gases, organics, and nitrogen oxides.
60.34b Emission guidelines for municipal waste combustor operating
practices.
60.35b Emission guidelines for municipal waste combustor operator
training and certification.
60.36b Emission guidelines for municipal waste combustor fugitive ash
emissions.
60.37b Emission guidelines for air curtain incinerators.
60.38b Compliance and performance testing.
60.39b Reporting and recordkeeping guidelines and compliance schedules.
Subpart Cc--Emission Guidelines and Compliance Times for Municipal Solid
Waste Landfills
60.30c Scope.
60.31c Definitions.
60.32c Designated facilities.
60.33c Emission guidelines for municipal solid waste landfill
emissions.
60.34c Test methods and procedures.
60.35c Reporting and recordkeeping guidelines.
60.36c Compliance times.
Subpart Cd--Emissions Guidelines and Compliance Times for Sulfuric Acid
Production Units
60.30d Designated facilities.
60.31d Emissions guidelines.
60.32d Compliance times.
Subpart Ce--Emission Guidelines and Compliance Times for Hospital/
Medical/Infectious Waste Incinerators
60.30e Scope.
60.31e Definitions.
60.32e Designated facilities.
60.33e Emission guidelines.
60.34e Operator training and qualification guidelines.
60.35e Waste management guidelines.
60.36e Inspection guidelines.
60.37e Compliance, performance testing, and monitoring guidelines.
[[Page 6]]
60.38e Reporting and recordkeeping guidelines.
60.39e Compliance times.
Table 1 to Subpart Ce--Emission Limits for Small, Medium, and Large
HMIWI
Table 2 to Subpart Ce--Emission Limits for Small HMIWI which meet the
criteria under Sec. 60.33e(b)
Subpart D--Standards of Performance for Fossil-Fuel-Fired Steam
Generators for Which Construction is Commenced After August 17, 1971
60.40 Applicability and designation of affected facility.
60.41 Definitions.
60.42 Standard for particulate matter.
60.43 Standard for sulfur dioxide.
60.44 Standard for nitrogen oxides.
60.45 Emission and fuel monitoring.
60.46 Test methods and procedures.
Subpart Da--Standards of Performance for Electric Utility Steam
Generating Units for Which Construction is Commenced After September 18,
1978
60.40a Applicability and designation of affected facility.
60.41a Definitions.
60.42a Standard for particulate matter.
60.43a Standard for sulfur dioxide.
60.44a Standard for nitrogen oxides.
60.45a Commercial demonstration permit.
60.46a Compliance provisions.
60.47a Emission monitoring.
60.48a Compliance determination procedures and methods.
60.49a Reporting requirements.
Subpart Db--Standards of Performance for Industrial-Commercial-
Institutional Steam Generating Units
60.40b Applicability and delegation of authority.
60.41b Definitions.
60.42b Standard for sulfur dioxide.
60.43b Standard for particulate matter.
60.44b Standard for nitrogen oxides.
60.45b Compliance and performance test methods and procedures for
sulfur dioxide.
60.46b Compliance and performance test methods and procedures for
particulate matter and nitrogen oxides.
60.47b Emission monitoring for sulfur dioxide.
60.48b Emission monitoring for particulate matter and nitrogen oxides.
60.49b Reporting and recordkeeping requirements.
Subpart Dc--Standards of Performance for Small Industrial-Commercial-
Institutional Steam Generating Units
60.40c Applicability and delegation of authority.
60.41c Definitions.
60.42c Standard for sulfur dioxide.
60.43c Standard for particulate matter.
60.44c Compliance and performance test methods and procedures for
sulfur dioxide.
60.45c Compliance and performance test methods and procedures for
particulate matter.
60.46c Emission monitoring for sulfur dioxide.
60.47c Emission monitoring for particulate matter.
60.48c Reporting and recordkeeping requirements.
Subpart E--Standards of Performance for Incinerators
60.50 Applicability and designation of affected facility.
60.51 Definitions.
60.52 Standard for particulate matter.
60.53 Monitoring of operations.
60.54 Test methods and procedures.
Subpart Ea--Standards of Performance for Municipal Waste Combustors for
Which Construction is Commenced After December 20, 1989 and on or Before
September 20, 1994
60.50a Applicability and delegation of authority.
60.51a Definitions.
60.52a Standard for municipal waste combustor metals.
60.53a Standard for municipal waste combustor organics.
60.54a Standard for municipal waste combustor acid gases.
60.55a Standard for nitrogen oxides.
60.56a Standard for municipal waste combustor operating practices.
60.57a [Reserved]
60.58a Compliance and performance testing.
60.59a Reporting and recordkeeping requirements.
Subpart Eb--Standards of Performance for Large Municipal Waste
Combustors for Which Construction is Commenced After September 20, 1994
or for Which Modification or Reconstruction is Commenced After June 19,
1996
60.50b Applicability and delegation of authority.
60.51b Definitions.
[[Page 7]]
60.52b Standards for municipal waste combustor metals, acid gases,
organics, and nitrogen oxides.
60.53b Standards for municipal waste combustor operating practices.
60.54b Standards for municipal waste combustor operator training and
certification.
60.55b Standards for municipal waste combustor fugitive ash emissions.
60.56b Standards for air curtain incinerators.
60.57b Siting requirements.
60.58b Compliance and performance testing.
60.59b Reporting and recordkeeping requirements.
Subpart Ec--Standards of Performance for Hospital/Medical/Infectious
Waste Incinerators for Which Construction is Commenced After June 20,
1996
60.50c Applicability and delegation of authority.
60.51c Definitions.
60.52c Emission limits.
60.53c Operator training and qualification requirements.
60.54c Siting requirements.
60.55c Waste management plan.
60.56c Compliance and performance testing.
60.57c Monitoring requirements.
60.58c Reporting and recordkeeping requirements.
Table 1 to Subpart Ec--Emission Limits for Small, Medium, and Large
HMIWI
Table 2 to Subpart Ec--Toxic Equivalency Factors
Table 3 to Subpart Ec--Operating Parameters to be Monitored and Minimum
Measurement and Recording Frequencies
Subpart F--Standards of Performance for Portland Cement Plants
60.60 Applicability and designation of affected facility.
60.61 Definitions.
60.62 Standard for particulate matter.
60.63 Monitoring of operations.
60.64 Test methods and procedures.
60.65 Recordkeeping and reporting requirements.
60.66 Delegation of authority.
Subpart G--Standards of Performance for Nitric Acid Plants
60.70 Applicability and designation of affected facility.
60.71 Definitions.
60.72 Standard for nitrogen oxides.
60.73 Emission monitoring.
60.74 Test methods and procedures.
Subpart H--Standards of Performance for Sulfuric Acid Plants
60.80 Applicability and designation of affected facility.
60.81 Definitions.
60.82 Standard for sulfur dioxide.
60.83 Standard for acid mist.
60.84 Emission monitoring.
60.85 Test methods and procedures.
Subpart I--Standards of Performance for Hot Mix Asphalt Facilities
60.90 Applicability and designation of affected facility.
60.91 Definitions.
60.92 Standard for particulate matter.
60.93 Test methods and procedures.
Subpart J--Standards of Performance for Petroleum Refineries
60.100 Applicability, designation of affected facility, and
reconstruction.
60.101 Definitions.
60.102 Standard for particulate matter.
60.103 Standard for carbon monoxide.
60.104 Standards for sulfur oxides.
60.105 Monitoring of emissions and operations.
60.106 Test methods and procedures.
60.107 Reporting and recordkeeping requirements.
60.108 Performance test and compliance provisions.
60.109 Delegation of authority.
Subpart K--Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification
Commenced After June 11, 1973, and Prior to May 19, 1978
60.110 Applicability and designation of affected facility.
60.111 Definitions.
60.112 Standard for volatile organic compounds (VOC).
60.113 Monitoring of operations.
Subpart Ka--Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification
Commenced After May 18, 1978, and Prior to July 23, 1984
60.110a Applicability and designation of affected facility.
60.111a Definitions.
60.112a Standard for volatile organic compounds (VOC).
60.113a Testing and procedures.
60.114a Alternative means of emission limitation.
60.115a Monitoring of operations.
[[Page 8]]
Subpart Kb--Standards of Performance for Volatile Organic Liquid Storage
Vessels (Including Petroleum Liquid Storage Vessels) for Which
Construction, Reconstruction, or Modification Commenced After July 23,
1984
60.110b Applicability and designation of affected facility.
60.111b Definitions.
60.112b Standard for volatile organic compounds (VOC).
60.113b Testing and procedures.
60.114b Alternative means of emission limitation.
60.115b Reporting and recordkeeping requirements.
60.116b Monitoring of operations.
60.117b Delegation of authority.
Subpart L--Standards of Performance for Secondary Lead Smelters
60.120 Applicability and designation of affected facility.
60.121 Definitions.
60.122 Standard for particulate matter.
60.123 Test methods and procedures.
Subpart M--Standards of Performance for Secondary Brass and Bronze
Production Plants
60.130 Applicability and designation of affected facility.
60.131 Definitions.
60.132 Standard for particulate matter.
60.133 Test methods and procedures.
Subpart N--Standards of Performance for Primary Emissions from Basic
Oxygen Process Furnances for Which Construction is Commenced After June
11, 1973
60.140 Applicability and designation of affected facility.
60.141 Definitions.
60.142 Standard for particulate matter.
60.143 Monitoring of operations.
60.144 Test methods and procedures.
Subpart Na--Standards of Performance for Secondary Emissions from Basic
Oxygen Process Steelmaking Facilities for Which Construction is
Commenced After January 20, 1983
60.140a Applicability and designation of affected facilities.
60.141a Definitions.
60.142a Standards for particulate matter.
60.143a Monitoring of operations.
60.144a Test methods and procedures.
60.145a Compliance provisions.
Subpart O--Standards of Performance for Sewage Treatment Plants
60.150 Applicability and designation of affected facility.
60.151 Definitions.
60.152 Standard for particulate matter.
60.153 Monitoring of operations.
60.154 Test methods and procedures.
60.155 Reporting.
60.156 Delegation of authority.
Subpart P--Standards of Performance for Primary Copper Smelters
60.160 Applicability and designation of affected facility.
60.161 Definitions.
60.162 Standard for particulate matter.
60.163 Standard for sulfur dioxide.
60.164 Standard for visible emissions.
60.165 Monitoring of operations.
60.166 Test methods and procedures.
Subpart Q--Standards of Performance for Primary Zinc Smelters
60.170 Applicability and designation of affected facility.
60.171 Definitions.
60.172 Standard for particulate matter.
60.173 Standard for sulfur dioxide.
60.174 Standard for visible emissions.
60.175 Monitoring of operations.
60.176 Test methods and procedures.
Subpart R--Standards of Performance for Primary Lead Smelters
60.180 Applicability and designation of affected facility.
60.181 Definitions.
60.182 Standard for particulate matter.
60.183 Standard for sulfur dioxide.
60.184 Standard for visible emissions.
60.185 Monitoring of operations.
60.186 Test methods and procedures.
Subpart S--Standards of Performance for Primary Aluminum Reduction
Plants
60.190 Applicability and designation of affected facility.
60.191 Definitions.
60.192 Standard for fluorides.
60.193 Standard for visible emissions.
60.194 Monitoring of operations.
60.195 Test methods and procedures.
Subpart T--Standards of Performance for the Phosphate Fertilizer
Industry: Wet-Process Phosphoric Acid Plants
60.200 Applicability and designation of affected facility.
60.201 Definitions.
60.202 Standard for fluorides.
[[Page 9]]
60.203 Monitoring of operations.
60.204 Test methods and procedures.
Subpart U--Standards of Performance for the Phosphate Fertilizer
Industry: Superphosphoric Acid Plants
60.210 Applicability and designation of affected facility.
60.211 Definitions.
60.212 Standard for fluorides.
60.213 Monitoring of operations.
60.214 Test methods and procedures.
Subpart V--Standards of Performance for the Phosphate Fertilizer
Industry: Diammonium Phosphate Plants
60.220 Applicability and designation of affected facility.
60.221 Definitions.
60.222 Standard for fluorides.
60.223 Monitoring of operations.
60.224 Test methods and procedures.
Subpart W--Standards of Performance for the Phosphate Fertilizer
Industry: Triple Superphosphate Plants
60.230 Applicability and designation of affected facility.
60.231 Definitions.
60.232 Standard for fluorides.
60.233 Monitoring of operations.
60.234 Test methods and procedures.
Subpart X--Standards of Performance for the Phosphate Fertilizer
Industry: Granular Triple Superphosphate Storage Facilities
60.240 Applicability and designation of affected facility.
60.241 Definitions.
60.242 Standard for fluorides.
60.243 Monitoring of operations.
60.244 Test methods and procedures.
Subpart Y--Standards of Performance for Coal Preparation Plants
60.250 Applicability and designation of affected facility.
60.251 Definitions.
60.252 Standards for particulate matter.
60.253 Monitoring of operations.
60.254 Test methods and procedures.
Subpart Z--Standards of Performance for Ferroalloy Production Facilities
60.260 Applicability and designation of affected facility.
60.261 Definitions.
60.262 Standard for particulate matter.
60.263 Standard for carbon monoxide.
60.264 Emission monitoring.
60.265 Monitoring of operations.
60.266 Test methods and procedures.
Subpart AA--Standards of Performance for Steel Plants: Electric Arc
Furnaces Constructed After October 21, 1974 and On or Before August 17,
1983
60.270 Applicability and designation of affected facility.
60.271 Definitions.
60.272 Standard for particulate matter.
60.273 Emission monitoring.
60.274 Monitoring of operations.
60.275 Test methods and procedures.
60.276 Recordkeeping and reporting requirements.
Subpart AAa--Standards of Performance for Steel Plants: Electric Arc
Furnaces and Argon-Oxygen Decarburization Vessels Constructed After
August 7, 1983
60.270a Applicability and designation of affected facility.
60.271a Definitions.
60.272a Standard for particulate matter.
60.273a Emission monitoring.
60.274a Monitoring of operations.
60.275a Test methods and procedures.
60.276a Recordkeeping and reporting requirements.
Subpart BB--Standards of Performance for Kraft Pulp Mills
60.280 Applicability and designation of affected facility.
60.281 Definitions.
60.282 Standard for particulate matter.
60.283 Standard for total reduced sulfur (TRS).
60.284 Monitoring of emissions and operations.
60.285 Test methods and procedures.
Subpart CC--Standards of Performance for Glass Manufacturing Plants
60.290 Applicability and designation of affected facility.
60.291 Definitions.
60.292 Standards for particulate matter.
60.293 Standards for particulate matter from glass melting furnace with
modified-processes.
60.294--60.295 [Reserved]
60.296 Test methods and procedures.
Subpart DD--Standards of Performance for Grain Elevators
60.300 Applicability and designation of affected facility.
60.301 Definitions.
60.302 Standard for particulate matter.
60.303 Test methods and procedures.
[[Page 10]]
60.304 Modifications.
Subpart EE--Standards of Performance for Surface Coating of Metal
Furniture
60.310 Applicability and designation of affected facility.
60.311 Definitions and symbols.
60.312 Standard for volatile organic compounds (VOC).
60.313 Performance tests and compliance provisions.
60.314 Monitoring of emissions and operations.
60.315 Reporting and recordkeeping requirements.
60.316 Test methods and procedures.
Subpart FF [Reserved]
Subpart GG--Standards of Performance for Stationary Gas Turbines
60.330 Applicability and designation of affected facility.
60.331 Definitions.
60.332 Standard for nitrogen oxides.
60.333 Standard for sulfur dioxide.
60.334 Monitoring of operations.
60.335 Test methods and procedures.
Subpart HH--Standards of Performance for Lime Manufacturing Plants
60.340 Applicability and designation of affected facility.
60.341 Definitions.
60.342 Standard for particulate matter.
60.343 Monitoring of emissions and operations.
60.344 Test methods and procedures.
Subpart KK--Standards of Performance for Lead-Acid Battery Manufacturing
Plants
60.370 Applicability and designation of affected facility.
60.371 Definitions.
60.372 Standards for lead.
60.373 Monitoring of emissions and operations.
60.374 Test methods and procedures.
Subpart LL--Standards of Performance for Metallic Mineral Processing
Plants
60.380 Applicability and designation of affected facility.
60.381 Definitions.
60.382 Standard for particulate matter.
60.383 Reconstruction.
60.384 Monitoring of operations.
60.385 Recordkeeping and reporting requirements.
60.386 Test methods and procedures.
Subpart MM--Standards of Performance for Automobile and Light Duty Truck
Surface Coating Operations
60.390 Applicability and designation of affected facility.
60.391 Definitions.
60.392 Standards for volatile organic compounds.
60.393 Performance test and compliance provisions.
60.394 Monitoring of emissions and operations.
60.395 Reporting and recordkeeping requirements.
60.396 Reference methods and procedures.
60.397 Modifications.
60.398 Innovative technology waivers.
Subpart NN--Standards of Performance for Phosphate Rock Plants
60.400 Applicability and designation of affected facility.
60.401 Definitions.
60.402 Standard for particulate matter.
60.403 Monitoring of emissions and operations.
60.404 Test methods and procedures.
Subpart PP--Standards of Performance for Ammonium Sulfate Manufacture
60.420 Applicability and designation of affected facility.
60.421 Definitions.
60.422 Standards for particulate matter.
60.423 Monitoring of operations.
60.424 Test methods and procedures.
Subpart QQ--Standards of Performance for the Graphic Arts Industry:
Publication Rotogravure Printing
60.430 Applicability and designation of affected facility.
60.431 Definitions and notations.
60.432 Standard for volatile organic compounds.
60.433 Performance test and compliance provisions.
60.434 Monitoring of operations and recordkeeping.
60.435 Test methods and procedures.
Subpart RR--Standards of Performance for Pressure Sensitive Tape and
Label Surface Coating Operations
60.440 Applicability and designation of affected facility.
60.441 Definitions and symbols.
60.442 Standard for volatile organic compounds.
60.443 Compliance provisions.
60.444 Performance test procedures.
[[Page 11]]
60.445 Monitoring of operations and recordkeeping.
60.446 Test methods and procedures.
60.447 Reporting requirements.
Subpart SS--Standards of Performance for Industrial Surface Coating:
Large Appliances
60.450 Applicability and designation of affected facility.
60.451 Definitions.
60.452 Standard for volatile organic compounds.
60.453 Performance test and compliance provisions.
60.454 Monitoring of emissions and operations.
60.455 Reporting and recordkeeping requirements.
60.456 Test methods and procedures.
Subpart TT--Standards of Performance for Metal Coil Surface Coating
60.460 Applicability and designation of affected facility.
60.461 Definitions.
60.462 Standards for volatile organic compounds.
60.463 Performance test and compliance provisions.
60.464 Monitoring of emissions and operations.
60.465 Reporting and recordkeeping requirements.
60.466 Test methods and procedures.
Subpart UU--Standards of Performance for Asphalt Processing and Asphalt
Roofing Manufacture
60.470 Applicability and designation of affected facilities.
60.471 Definitions.
60.472 Standards for particulate matter.
60.473 Monitoring of operations.
60.474 Test methods and procedures.
Subpart VV--Standards of Performance for Equipment Leaks of VOC in the
Synthetic Organic Chemicals Manufacturing Industry
60.480 Applicability and designation of affected facility.
60.481 Definitions.
60.482-1 Standards: General.
60.482-2 Standards: Pumps in light liquid service.
60.482-3 Standards: Compressors.
60.482-4 Standards: Pressure relief devices in gas/vapor service.
60.482-5 Standards: Sampling connection systems.
60.482-6 Standards: Open-ended valves or lines.
60.482-7 Standards: Valves in gas/vapor service and in light liquid
service.
60.482-8 Standards: Pumps and valves in heavy liquid service, pressure
relief devices in light liquid or heavy liquid service, and
connectors.
60.482-9 Standards: Delay of repair.
60.482-10 Standards: Closed vent systems and control devices.
60.483-1 Alternative standards for valves--allowable percentage of
valves leaking.
60.483-2 Alternative standards for valves--skip period leak detection
and repair.
60.484 Equivalence of means of emission limitation.
60.485 Test methods and procedures.
60.486 Recordkeeping requirements.
60.487 Reporting requirements.
60.488 Reconstruction.
60.489 List of chemicals produced by affected facilities.
Subpart WW--Standards of Performance for the Beverage Can Surface
Coating Industry
60.490 Applicability and designation of affected facility.
60.491 Definitions.
60.492 Standards for volatile organic compounds.
60.493 Performance test and compliance provisions.
60.494 Monitoring of emissions and operations.
60.495 Reporting and recordkeeping requirements.
60.496 Test methods and procedures.
Subpart XX--Standards of Performance for Bulk Gasoline Terminals
60.500 Applicability and designation of affected facility.
60.501 Definitions.
60.502 Standards for Volatile Organic Compound (VOC) emissions from
bulk gasoline terminals.
60.503 Test methods and procedures.
60.504 [Reserved]
60.505 Reporting and recordkeeping.
60.506 Reconstruction.
Subpart AAA--Standards of Performance for New Residential Wood Heaters
60.530 Applicability and designation of affected facility.
60.531 Definitions.
60.532 Standards for particulate matter.
60.533 Compliance and certification.
60.534 Test methods and procedures.
60.535 Laboratory accreditation.
60.536 Permanent label, temporary label, and owner's manual.
60.537 Reporting and recordkeeping.
60.538 Prohibitions.
[[Page 12]]
60.539 Hearing and appeal procedures.
60.539a Delegation of authority.
60.539b General provisions exclusions.
Subpart BBB--Standards of Performance for the Rubber Tire Manufacturing
Industry
60.540 Applicability and designation of affected facilities.
60.541 Definitions.
60.542 Standards for volatile organic compounds.
60.542a Alternate standard for volatile organic compounds.
60.543 Performance test and compliance provisions.
60.544 Monitoring of operations.
60.545 Recordkeeping requirements.
60.546 Reporting requirements.
60.547 Test methods and procedures.
60.548 Delegation of authority.
Subpart CCC [Reserved]
Subpart DDD--Standards of Performance for Volatile Organic Compound
(VOC) Emissions from the Polymer Manufacturing Industry
60.560 Applicability and designation of affected facilities.
60.561 Definitions.
60.562-1 Standards: Process emissions.
60.562-2 Standards: Equipment leaks of VOC.
60.563 Monitoring requirements.
60.564 Test methods and procedures.
60.565 Reporting and recordkeeping requirements.
60.566 Delegation of authority.
Subpart EEE [Reserved]
Subpart FFF--Standards of Performance for Flexible Vinyl and Urethane
Coating and Printing
60.580 Applicability and designation of affected facility.
60.581 Definitions and symbols.
60.582 Standard for volatile organic compounds.
60.583 Test methods and procedures.
60.584 Monitoring of operations and recordkeeping requirements.
60.585 Reporting requirements.
Subpart GGG--Standards of Performance for Equipment Leaks of VOC in
Petroleum Refineries
60.590 Applicability and designation of affected facility.
60.591 Definitions.
60.592 Standards.
60.593 Exceptions.
Subpart HHH--Standards of Performance for Synthetic Fiber Production
Facilities
60.600 Applicability and designation of affected facility.
60.601 Definitions.
60.602 Standard for volatile organic compounds.
60.603 Performance test and compliance provisions.
60.604 Reporting requirements.
Subpart III--Standards of Performance for Volatile Organic Compound
(VOC) Emissions From the Synthetic Organic Chemical Manufacturing
Industry (SOCMI) Air Oxidation Unit Processes
60.610 Applicability and designation of affected facility.
60.611 Definitions.
60.612 Standards.
60.613 Monitoring of emissions and operations.
60.614 Test methods and procedures.
60.615 Reporting and recordkeeping requirements.
60.616 Reconstruction.
60.617 Chemicals affected by subpart III.
60.618 Delegation of authority.
Subpart JJJ--Standards of Performance for Petroleum Dry Cleaners
60.620 Applicability and designation of affected facility.
60.621 Definitions.
60.622 Standards for volatile organic compounds.
60.623 Equivalent equipment and procedures.
60.624 Test methods and procedures.
60.625 Recordkeeping requirements.
Subpart KKK--Standards of Performance for Equipment Leaks of VOC From
Onshore Natural Gas Processing Plants
60.630 Applicability and designation of affected facility.
60.631 Definitions.
60.632 Standards.
60.633 Exceptions.
60.634 Alternative means of emission limitation.
60.635 Recordkeeping requirements.
60.636 Reporting requirements.
Subpart LLL--Standards of Performance for Onshore Natural Gas
Processing: SO2 Emissions
60.640 Applicability and designation of affected facilities.
60.641 Definitions.
60.642 Standards for sulfur dioxide.
60.643 Compliance provisions.
[[Page 13]]
60.644 Test methods and procedures.
60.645 [Reserved]
60.646 Monitoring of emissions and operations.
60.647 Recordkeeping and reporting requirements.
60.648 Optional procedure for measuring hydrogen sulfide in acid gas--
Tutwiler Procedure.
Subpart MMM [Reserved]
Subpart NNN--Standards of Performance for Volatile Organic Compound
(VOC) Emissions From Synthetic Organic Chemical Manufacturing Industry
(SOCMI) Distillation Operations
60.660 Applicability and designation of affected facility.
60.661 Definitions.
60.662 Standards.
60.663 Monitoring of emissions and operations.
60.664 Test methods and procedures.
60.665 Reporting and recordkeeping requirements.
60.666 Reconstruction.
60.667 Chemicals affected by subpart NNN.
60.668 Delegation of authority.
Subpart OOO--Standards of Performance for Nonmetallic Mineral Processing
Plants
60.670 Applicability and designation of affected facility.
60.671 Definitions.
60.672 Standard for particulate matter.
60.673 Reconstruction.
60.674 Monitoring of operations.
60.675 Test methods and procedures.
60.676 Reporting and recordkeeping.
Subpart PPP--Standard of Performance for Wool Fiberglass Insulation
Manufacturing Plants
60.680 Applicability and designation of affected facility.
60.681 Definitions.
60.682 Standard for particulate matter.
60.683 Monitoring of operations.
60.684 Recordkeeping and reporting requirements.
60.685 Test methods and procedures.
Subpart QQQ--Standards of Performance for VOC Emissions From Petroleum
Refinery Wastewater Systems
60.690 Applicability and designation of affected facility.
60.691 Definitions.
60.692-1 Standards: General.
60.692-2 Standards: Individual drain systems.
60.692-3 Standards: Oil-water separators.
60.692-4 Standards: Aggregate facility.
60.692-5 Standards: Closed vent systems and control devices.
60.692-6 Standards: Delay of repair.
60.692-7 Standards: Delay of compliance.
60.693-1 Alternative standards for individual drain systems.
60.693-2 Alternative standards for oil-water separators.
60.694 Permission to use alternative means of emission limitation.
60.695 Monitoring of operations.
60.696 Performance test methods and procedures and compliance
provisions.
60.697 Recordkeeping requirements.
60.698 Reporting requirements.
60.699 Delegation of authority.
Subpart RRR--Standards of Performance for Volatile Organic Compound
Emissions from Synthetic Organic Chemical Manufacturing Industry (SOCMI)
Reactor Processes
60.700 Applicability and designation of affected facility.
60.701 Definitions.
60.702 Standards.
60.703 Monitoring of emissions and operations.
60.704 Test methods and procedures.
60.705 Reporting and recordkeeping requirements.
60.706 Reconstruction.
60.707 Chemicals affected by subpart RRR.
60.708 Delegation of authority.
Subpart SSS--Standards of Performance for Magnetic Tape Coating
Facilities
60.710 Applicability and designation of affected facility.
60.711 Definitions, symbols, and cross-reference tables.
60.712 Standards for volatile organic compounds.
60.713 Compliance provisions.
60.714 Installation of monitoring devices and recordkeeping.
60.715 Test methods and procedures.
60.716 Permission to use alternative means of emission limitation.
60.717 Reporting and monitoring requirements.
60.718 Delegation of authority.
Subpart TTT--Standards of Performance for Industrial Surface Coating:
Surface Coating of Plastic Parts for Business Machines
60.720 Applicability and designation of affected facility.
60.721 Definitions.
60.722 Standards for volatile organic compounds.
60.723 Performance test and compliance provisions.
[[Page 14]]
60.724 Reporting and recordkeeping requirements.
60.725 Test methods and procedures.
60.726 Delegation of authority.
Subpart UUU--Standards of Performance for Calciners and Dryers in
Mineral Industries
60.730 Applicability and designation of affected facility.
60.731 Definitions.
60.732 Standards for particulate matter.
60.733 Reconstruction.
60.734 Monitoring of emissions and operations.
60.735 Recordkeeping and reporting requirements.
60.736 Test methods and procedures.
60.737 Delegation of authority.
Subpart VVV--Standards of Performance for Polymeric Coating of
Supporting Substrates Facilities
60.740 Applicability and designation of affected facility.
60.741 Definitions, symbols, and cross-reference tables.
60.742 Standards for violatile organic compounds.
60.743 Compliance provisions.
60.744 Monitoring requirements.
60.745 Test methods and procedures.
60.746 Permission to use alternative means of emission limitation.
60.747 Reporting and recordkeeping requirements.
60.748 Delegation of authority.
Subpart WWW--Standards of Performance for Municipal Solid Waste
Landfills
60.750 Applicability, designation of affected facility, and delegation
of authority.
60.751 Definitions.
60.752 Standards for air emissions from municipal solid waste
landfills.
60.753 Operational standards for collection and control systems.
60.754 Test methods and procedures.
60.755 Compliance provisions.
60.756 Monitoring of operations.
60.757 Reporting requirements.
60.758 Recordkeeping requirements.
60.759 Specifications for active collection systems.
Subpart AAAA--Standards of Performance for Small Municipal Waste
Combustion Units for Which Construction is Commenced After August 30,
1999 or for Which Modification or Reconstruction is Commenced After June
6, 2001
Introduction
60.1000 What does this subpart do?
60.1005 When does this subpart become effective?
Applicability
60.1010 Does this subpart apply to my municipal waste combustion unit?
60.1015 What is a new municipal waste combustion unit?
60.1020 Does this subpart allow any exemptions?
60.1025 Do subpart E new source performance standards also apply to my
municipal waste combustion unit?
60.1030 Can the Administrator delegate authority to enforce these
Federal new source performance standards to a State agency?
60.1035 How are these new source performance standards structured?
60.1040 Do all five components of these new source performance
standards apply at the same time?
60.1045 Are there different subcategories of small municipal waste
combustion units within this subpart?
Preconstruction Requirements: Materials Separation Plan
60.1050 Who must submit a materials separation plan?
60.1055 What is a materials separation plan?
60.1060 What steps must I complete for my materials separation plan?
60.1065 What must I include in my draft materials separation plan?
60.1070 How do I make my draft materials separation plan available to
the public?
60.1075 When must I accept comments on the materials separation plan?
60.1080 Where and when must I hold a public meeting on my draft
materials separation plan?
60.1085 What must I do with any public comments I receive during the
public comment period on my draft materials separation plan?
60.1090 What must I do with my revised materials separation plan?
60.1095 What must I include in the public meeting on my revised
materials separation plan?
[[Page 15]]
60.1100 What must I do with any public comments I receive on my revised
materials separation plan?
60.1105 How do I submit my final materials separation plan?
Preconstruction Requirements: Siting Analysis
60.1110 Who must submit a siting analysis?
60.1115 What is a siting analysis?
60.1120 What steps must I complete for my siting analysis?
60.1125 What must I include in my siting analysis?
60.1130 How do I make my siting analysis available to the public?
60.1135 When must I accept comments on the siting analysis and revised
materials separation plan?
60.1140 Where and when must I hold a public meeting on the siting
analysis?
60.1145 What must I do with any public comments I receive during the
public comment period on my siting analysis?
60.1150 How do I submit my siting analysis?
Good Combustion Practices: Operator Training
60.1155 What types of training must I do?
60.1160 Who must complete the operator training course? By when?
60.1165 Who must complete the plant-specific training course?
60.1170 What plant-specific training must I provide?
60.1175 What information must I include in the plant-specific operating
manual?
60.1180 Where must I keep the plant-specific operating manual?
Good Combustion Practices: Operator Certification
60.1185 What types of operator certification must the chief facility
operator and shift supervisor obtain and by when must they
obtain it?
60.1190 After the required date for operator certification, who may
operate the municipal waste combustion unit?
60.1195 What if all the certified operators must be temporarily
offsite?
Good Combustion Practices: Operating Requirements
60.1200 What are the operating practice requirements for my municipal
waste combustion unit?
60.1205 What happens to the operating requirements during periods of
startup, shutdown, and malfunction?
Emission Limits
60.1210 What pollutants are regulated by this subpart?
60.1215 What emission limits must I meet? By when?
60.1220 What happens to the emission limits during periods of startup,
shutdown, and malfunction?
Continuous Emission Monitoring
60.1225 What types of continuous emission monitoring must I perform?
60.1230 What continuous emission monitoring systems must I install for
gaseous pollutants?
60.1235 How are the data from the continuous emission monitoring
systems used?
60.1240 How do I make sure my continuous emission monitoring systems
are operating correctly?
60.1245 Am I exempt from any appendix B or appendix F requirements to
evaluate continuous emission monitoring systems?
60.1250 What is my schedule for evaluating continuous emission
monitoring systems?
60.1255 What must I do if I choose to monitor carbon dioxide instead of
oxygen as a diluent gas?
60.1260 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems and is the data
collection requirement enforceable?
60.1265 How do I convert my 1-hour arithmetic averages into the
appropriate averaging times and units?
60.1270 What is required for my continuous opacity monitoring system
and how are the data used?
60.1275 What additional requirements must I meet for the operation of
my continuous emission monitoring systems and continuous
opacity monitoring system?
60.1280 What must I do if any of my continuous emission monitoring
systems are temporarily unavailable to meet the data
collection requirements?
Stack Testing
60.1285 What types of stack tests must I conduct?
60.1290 How are the stack test data used?
60.1295 What schedule must I follow for the stack testing?
60.1300 What test methods must I use to stack test?
60.1305 May I conduct stack testing less often?
60.1310 May I deviate from the 13-month testing schedule if unforeseen
circumstances arise?
Other Monitoring Requirements
60.1315 Must I meet other requirements for continuous monitoring?
60.1320 How do I monitor the load of my municipal waste combustion
unit?
[[Page 16]]
60.1325 How do I monitor the temperature of flue gases at the inlet of
my particulate matter control device?
60.1330 How do I monitor the injection rate of activated carbon?
60.1335 What is the minimum amount of monitoring data I must collect
with my continuous parameter monitoring systems and is the
data collection requirement enforceable?
Recordkeeping
60.1340 What records must I keep?
60.1345 Where must I keep my records and for how long?
60.1350 What records must I keep for the materials separation plan and
siting analysis?
60.1355 What records must I keep for operator training and
certification?
60.1360 What records must I keep for stack tests?
60.1365 What records must I keep for continuously monitored pollutants
or parameters?
60.1370 What records must I keep for municipal waste combustion units
that use activated carbon?
Reporting
60.1375 What reports must I submit before I submit my notice of
construction?
60.1380 What must I include in my notice of construction?
60.1385 What reports must I submit after I submit my notice of
construction and in what form?
60.1390 What are the appropriate units of measurement for reporting my
data?
60.1395 When must I submit the initial report?
60.1400 What must I include in my initial report?
60.1405 When must I submit the annual report?
60.1410 What must I include in my annual report?
60.1415 What must I do if I am out of compliance with the requirements
of this subpart?
60.1420 If a semiannual report is required, when must I submit it?
60.1425 What must I include in the semiannual out-of-compliance
reports?
60.1430 Can reporting dates be changed?
Air Curtain Incinerators That Burn 100 Percent Yard Waste
60.1435 What is an air curtain incinerator?
60.1440 What is yard waste?
60.1445 What are the emission limits for air curtain incinerators that
burn 100 percent yard waste?
60.1450 How must I monitor opacity for air curtain incinerators that
burn 100 percent yard waste?
60.1455 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn 100 percent yard waste?
Equations
60.1460 What equations must I use?
Definitions
60.1465 What definitions must I know?
Tables
Table 1 of Subpart AAAA--Emission Limits For New Small Municipal Waste
Combustion Units
Table 2 of Subpart AAAA--Carbon Monoxide Emission Limits For New Small
Municipal Waste Combustion Units
Table 3 of Subpart AAAA--Requirements For Validating Continuous Emission
Monitoring Systems (CEMS)
Table 4 of Subpart AAAA--Requirements For Continuous Emission Monitoring
Systems (CEMS)
Table 5 of Subpart AAAA--Requirements For Stack Tests
Subpart BBBB--Emission Guidelines and Compliance Times for Small
Municipal Waste Combustion Units Constructed on or Before August 30,
1999
Introduction
60.1500 What is the purpose of this subpart?
60.1505 Am I affected by this subpart?
60.1510 Is a State plan required for all States?
60.1515 What must I include in my State plan?
60.1520 Is there an approval process for my State plan?
60.1525 What if my State plan is not approvable?
60.1530 Is there an approval process for a negative declaration letter?
60.1535 What compliance schedule must I include in my State plan?
60.1540 Are there any State plan requirements for this subpart that
supersede the requirements specified in subpart B?
60.1545 Does this subpart directly affect municipal waste combustion
unit owners and operators in my State?
Applicability of State Plans
60.1550 What municipal waste combustion units must I address in my
State plan?
60.1555 Are any small municipal waste combustion units exempt from my
State plan?
60.1560 Can an affected municipal waste combustion unit reduce its
capacity to less than 35 tons per day rather than comply with
my State plan?
[[Page 17]]
60.1565 What subcategories of small municipal waste combustion units
must I include in my State plan?
Use of Model Rule
60.1570 What is the ``model rule'' in this subpart?
60.1575 How does the model rule relate to the required elements of my
State plan?
60.1580 What are the principal components of the model rule?
Model Rule--Increments of Progress
60.1585 What are my requirements for meeting increments of progress and
achieving final compliance?
60.1590 When must I complete each increment of progress?
60.1595 What must I include in the notifications of achievement of my
increments of progress?
60.1600 When must I submit the notifications of achievement of
increments of progress?
60.1605 What if I do not meet an increment of progress?
60.1610 How do I comply with the increment of progress for submittal of
a control plan?
60.1615 How do I comply with the increment of progress for awarding
contracts?
60.1620 How do I comply with the increment of progress for initiating
onsite construction?
60.1625 How do I comply with the increment of progress for completing
onsite construction?
60.1630 How do I comply with the increment of progress for achieving
final compliance?
60.1635 What must I do if I close my municipal waste combustion unit
and then restart my municipal waste combustion unit?
60.1640 What must I do if I plan to permanently close my municipal
waste combustion unit and not restart it?
Model Rule--Good Combustion Practices: Operator Training
60.1645 What types of training must I do?
60.1650 Who must complete the operator training course? By when?
60.1655 Who must complete the plant-specific training course?
60.1660 What plant-specific training must I provide?
60.1665 What information must I include in the plant-specific operating
manual?
60.1670 Where must I keep the plant-specific operating manual?
Model Rule--Good Combustion Practices: Operator Certification
60.1675 What types of operator certification must the chief facility
operator and shift supervisor obtain and by when must they
obtain it?
60.1680 After the required date for operator certification, who may
operate the municipal waste combustion unit?
60.1685 What if all the certified operators must be temporarily
offsite?
Model Rule--Good Combustion Practices: Operating Requirements
60.1690 What are the operating practice requirements for my municipal
waste combustion unit?
60.1695 What happens to the operating requirements during periods of
startup, shutdown, and malfunction?
Model Rule--Emission Limits
60.1700 What pollutants are regulated by this subpart?
60.1705 What emission limits must I meet? By when?
60.1710 What happens to the emission limits during periods of startup,
shutdown, and malfunction?
Model Rule--Continuous Emission Monitoring
60.1715 What types of continuous emission monitoring must I perform?
60.1720 What continuous emission monitoring systems must I install for
gaseous pollutants?
60.1725 How are the data from the continuous emission monitoring
systems used?
60.1730 How do I make sure my continuous emission monitoring systems
are operating correctly?
60.1735 Am I exempt from any appendix B or appendix F requirements to
evaluate continuous emission monitoring systems?
60.1740 What is my schedule for evaluating continuous emission
monitoring systems?
60.1745 What must I do if I choose to monitor carbon dioxide instead of
oxygen as a diluent gas?
60.1750 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems and is the data
collection requirement enforceable?
60.1755 How do I convert my 1-hour arithmetic averages into appropriate
averaging times and units?
60.1760 What is required for my continuous opacity monitoring system
and how are the data used?
60.1765 What additional requirements must I meet for the operation of
my continuous emission monitoring systems and continuous
opacity monitoring system?
60.1770 What must I do if any of my continuous emission monitoring
systems are
[[Page 18]]
temporarily unavailable to meet the data collection
requirements?
Model Rule--Stack Testing
60.1775 What types of stack tests must I conduct?
60.1780 How are the stack test data used?
60.1785 What schedule must I follow for the stack testing?
60.1790 What test methods must I use to stack test?
60.1795 May I conduct stack testing less often?
60.1800 May I deviate from the 13-month testing schedule if unforeseen
circumstances arise?
Model Rule--Other Monitoring Requirements
60.1805 Must I meet other requirements for continuous monitoring?
60.1810 How do I monitor the load of my municipal waste combustion
unit?
60.1815 How do I monitor the temperature of flue gases at the inlet of
my particulate matter control device?
60.1820 How do I monitor the injection rate of activated carbon?
60.1825 What is the minimum amount of monitoring data I must collect
with my continuous parameter monitoring systems and is the
data collection requirement enforceable?
Model Rule--Recordkeeping
60.1830 What records must I keep?
60.1835 Where must I keep my records and for how long?
60.1840 What records must I keep for operator training and
certification?
60.1845 What records must I keep for stack tests?
60.1850 What records must I keep for continuously monitored pollutants
or parameters?
60.1855 What records must I keep for municipal waste combustion units
that use activated carbon?
Model Rule--Reporting
60.1860 What reports must I submit and in what form?
60.1865 What are the appropriate units of measurement for reporting my
data?
60.1870 When must I submit the initial report?
60.1875 What must I include in my initial report?
60.1880 When must I submit the annual report?
60.1885 What must I include in my annual report?
60.1890 What must I do if I am out of compliance with the requirements
of this subpart?
60.1895 If a semiannual report is required, when must I submit it?
60.1900 What must I include in the semiannual out-of-compliance
reports?
60.1905 Can reporting dates be changed?
Model Rule--Air Curtain Incinerators That Burn 100 Percent Yard Waste
60.1910 What is an air curtain incinerator?
60.1915 What is yard waste?
60.1920 What are the emission limits for air curtain incinerators that
burn 100 percent yard waste?
60.1925 How must I monitor opacity for air curtain incinerators that
burn 100 percent yard waste?
60.1930 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn 100 percent yard waste?
Equations
60.1935 What equations must I use?
Definitions
60.1940 What definitions must I know?
Tables
Table 1 of Subpart BBBB--Model Rule--Compliance Schedules and Increments
of Progress
Table 2 of Subpart BBBB--Model Rule--Class I Emission Limits For
Existing Small Municipal Waste Combustion Units
Table 3 of Subpart BBBB--Model Rule--Class I Nitrogen Oxides Emission
Limits For Existing Small Municipal Waste Combustion Units
Table 4 of Subpart BBBB--Model Rule--Class II Emission Limits For
Existing Small Municipal Waste Combustion Units
Table 5 of Subpart BBBB--Model Rule--Carbon Monoxide Emission Limits For
Existing Small Municipal Waste Combustion Units
Table 6 of Subpart BBBB--Model Rule--Requirements for Validating
Continuous Emission Monitoring Systems (CEMS)
Table 7 of Subpart BBBB--Model Rule--Requirements for Continuous
Emission Monitoring Systems (CEMS)
Table 8 of Subpart BBBB--Model Rule--Requirements for Stack Tests
[[Page 19]]
Subpart CCCC--Standards of Performance for Commercial and Industrial
Solid Waste Incineration Units for Which Construction Is Commenced After
November 30, 1999 or for Which Modification or Reconstruction Is
Commenced on or After June 1, 2001
Introduction
60.2000 What does this subpart do?
60.2005 When does this subpart become effective?
Applicability
60.2010 Does this subpart apply to my incineration unit?
60.2015 What is a new incineration unit?
60.2020 What combustion units are exempt from this subpart?
60.2025 What if my chemical recovery unit is not listed in
Sec. 60.2020(n)?
60.2030 Who implements and enforces this subpart?
60.2035 How are these new source performance standards structured?
60.2040 Do all eleven components of the new source performance
standards apply at the same time?
Preconstruction Siting Analysis
60.2045 Who must prepare a siting analysis?
60.2050 What is a siting analysis?
Waste Management Plan
60.2055 What is a waste management plan?
60.2060 When must I submit my waste management plan?
60.2065 What should I include in my waste management plan?
Operator Training and Qualification
60.2070 What are the operator training and qualification requirements?
60.2075 When must the operator training course be completed?
60.2080 How do I obtain my operator qualification?
60.2085 How do I maintain my operator qualification?
60.2090 How do I renew my lapsed operator qualification?
60.2095 What site-specific documentation is required?
60.2100 What if all the qualified operators are temporarily not
accessible?
Emission Limitations and Operating Limits
60.2105 What emission limitations must I meet and by when?
60.2110 What operating limits must I meet and by when?
60.2115 What if I do not use a wet scrubber to comply with the emission
limitations?
60.2120 What happens during periods of startup, shutdown, and
malfunction?
Performance Testing
60.2125 How do I conduct the initial and annual performance test?
60.2130 How are the performance test data used?
Initial Compliance Requirements
60.2135 How do I demonstrate initial compliance with the emission
limitations and establish the operating limits?
60.2140 By what date must I conduct the initial performance test?
Continuous Compliance Requirements
60.2145 How do I demonstrate continuous compliance with the emission
limitations and the operating limits?
60.2150 By what date must I conduct the annual performance test?
60.2155 May I conduct performance testing less often?
60.2160 May I conduct a repeat performance test to establish new
operating limits?
Monitoring
60.2165 What monitoring equipment must I install and what parameters
must I monitor?
60.2170 Is there a minimum amount of monitoring data I must obtain?
Recordkeeping and Reporting
60.2175 What records must I keep?
60.2180 Where and in what format must I keep my records?
60.2185 What reports must I submit?
60.2190 What must I submit prior to commencing construction?
60.2195 What information must I submit prior to initial startup?
60.2200 What information must I submit following my initial performance
test?
60.2205 When must I submit my annual report?
60.2210 What information must I include in my annual report?
60.2215 What else must I report if I have a deviation from the
operating limits or the emission limitations?
60.2220 What must I include in the deviation report?
60.2225 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.2230 Are there any other notifications or reports that I must
submit?
60.2235 In what form can I submit my reports?
60.2240 Can reporting dates be changed?
Title V Operating Permits
60.2242 Am I required to apply for and obtain a title V operating
permit for my unit?
[[Page 20]]
Air Curtain Incinerators
60.2245 What is an air curtain incinerator?
60.2250 What are the emission limitations for air curtain incinerators?
60.2255 How must I monitor opacity for air curtain incinerators?
60.2260 What are the recordkeeping and reporting requirements for air
curtain incinerators?
Definitions
60.2265 What definitions must I know?
Tables to Subpart CCCC
Table 1 to Subpart CCCC--Emission Limitations
Table 2 to Subpart CCCC--Operating Limits for Wet Scrubbers
Table 3 to Subpart CCCC--Toxic Equivalency Factors
Table 4 to Subpart CCCC--Summary of Reporting Requirements
Subpart DDDD--Emissions Guidelines and Compliance Times for Commercial
and Industrial Solid Waste Incineration Units that Commenced
Construction On or Before November 30, 1999
Introduction
60.2500 What is the purpose of this subpart?
60.2505 Am I affected by this subpart?
60.2510 Is a State plan required for all States?
60.2515 What must I include in my State plan?
60.2520 Is there an approval process for my State plan?
60.2525 What if my State plan is not approvable?
60.2530 Is there an approval process for a negative declaration letter?
60.2535 What compliance schedule must I include in my State plan?
60.2540 Are there any State plan requirements for this subpart that
apply instead of the requirements specified in subpart B?
60.2545 Does this subpart directly affect CISWI unit owners and
operators in my State?
Applicability of State Plans
60.2550 What CISWI units must I address in my State plan?
60.2555 What combustion units are exempt from my State plan?
60.2558 What if a chemical recovery unit is not listed in
Sec. 60.2555(n)?
Use of Model Rule
60.2560 What is the ``model rule'' in this subpart?
60.2565 How does the model rule relate to the required elements of my
State plan?
60.2570 What are the principal components of the model rule?
Model Rule--Increments of Progress
60.2575 What are my requirements for meeting increments of progress and
achieving final compliance?
60.2580 When must I complete each increment of progress?
60.2585 What must I include in the notifications of achievement of
increments of progress?
60.2590 When must I submit the notifications of achievement of
increments of progress?
60.2595 What if I do not meet an increment of progress?
60.2600 How do I comply with the increment of progress for submittal of
a control plan?
60.2605 How do I comply with the increment of progress for achieving
final compliance?
60.2610 What must I do if I close my CISWI unit and then restart it?
60.2615 What must I do if I plan to permanently close my CISWI unit and
not restart it?
Model Rule--Waste Management Plan
60.2620 What is a waste management plan?
60.2625 When must I submit my waste management plan?
60.2630 What should I include in my waste management plan?
Model Rule--Operator Training and Qualification
60.2635 What are the operator training and qualification requirements?
60.2640 When must the operator training course be completed?
60.2645 How do I obtain my operator qualification?
60.2650 How do I maintain my operator qualification?
60.2655 How do I renew my lapsed operator qualification?
60.2660 What site-specific documentation is required?
60.2665 What if all the qualified operators are temporarily not
accessible?
Model Rule--Emission Limitations and Operating Limits
60.2670 What emission limitations must I meet and by when?
60.2675 What operating limits must I meet and by when?
60.2680 What if I do not use a wet scrubber to comply with the emission
limitations?
60.2685 What happens during periods of startup, shutdown, and
malfunction?
[[Page 21]]
Model Rule--Performance Testing
60.2690 How do I conduct the initial and annual performance test?
60.2695 How are the performance test data used?
Model Rule--Initial Compliance Requirements
60.2700 How do I demonstrate initial compliance with the emission
limitations and establish the operating limits?
60.2705 By what date must I conduct the initial performance test?
Model Rule--Continuous Compliance Requirements
60.2710 How do I demonstrate continuous compliance with the emission
limitations and the operating limits?
60.2715 By what date must I conduct the annual performance test?
60.2720 May I conduct performance testing less often?
60.2725 May I conduct a repeat performance test to establish new
operating limits?
Model Rule--Monitoring
60.2730 What monitoring equipment must I install and what parameters
must I monitor?
60.2735 Is there a minimum amount of monitoring data I must obtain?
Model Rule--Recordkeeping and Reporting
60.2740 What records must I keep?
60.2745 Where and in what format must I keep my records?
60.2750 What reports must I submit?
60.2755 When must I submit my waste management plan?
60.2760 What information must I submit following my initial performance
test?
60.2765 When must I submit my annual report?
60.2770 What information must I include in my annual report?
60.2775 What else must I report if I have a deviation from the
operating limits or the emission limitations?
60.2780 What must I include in the deviation report?
60.2785 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.2790 Are there any other notifications or reports that I must
submit?
60.2795 In what form can I submit my reports?
60.2800 Can reporting dates be changed?
Model Rule--Title V Operating Permits
60.2805 Am I required to apply for and obtain a title V operating
permit for my unit?
Model Rule--Air Curtain Incinerators
60.2810 What is an air curtain incinerator?
60.2815 What are my requirements for meeting increments of progress and
achieving final compliance?
60.2820 When must I complete each increment of progress?
60.2825 What must I include in the notifications of achievement of
increments of progress?
60.2830 When must I submit the notifications of achievement of
increments of progress?
60.2835 What if I do not meet an increment of progress?
60.2840 How do I comply with the increment of progress for submittal of
a control plan?
60.2845 How do I comply with the increment of progress for achieving
final compliance?
60.2850 What must I do if I close my air curtain incinerator and then
restart it?
60.2855 What must I do if I plan to permanently close my air curtain
incinerator and not restart it?
60.2860 What are the emission limitations for air curtain incinerators?
60.2865 How must I monitor opacity for air curtain incinerators?
60.2870 What are the recordkeeping and reporting requirements for air
curtain incinerators?
Model Rule--Definitions
60.2875 What definitions must I know?
Tables to Subpart DDDD
Table 1 to Subpart DDDD--Model Rule--Increments of Progress and
Compliance Schedules
Table 2 to Subpart DDDD--Model Rule--Emission Limitations
Table 3 to Subpart DDDD--Model Rule--Operating Limits for Wet Scrubbers
Table 4 to Subpart DDDD--Model Rule--Toxic Equivalency Factors
Table 5 to Subpart DDDD--Model Rule--Summary of Reporting Requirements
Authority: 42 U.S.C. 7401 et seq.
Source: 36 FR 24877, Dec. 23, 1971, unless otherwise noted.
Subpart A--General Provisions
Sec. 60.1 Applicability.
(a) Except as provided in subparts B and C, the provisions of this
part apply to the owner or operator of any stationary source which
contains an affected facility, the construction or modification of which
is commenced after the date of publication in this
[[Page 22]]
part of any standard (or, if earlier, the date of publication of any
proposed standard) applicable to that facility.
(b) Any new or revised standard of performance promulgated pursuant
to section 111(b) of the Act shall apply to the owner or operator of any
stationary source which contains an affected facility, the construction
or modification of which is commenced after the date of publication in
this part of such new or revised standard (or, if earlier, the date of
publication of any proposed standard) applicable to that facility.
(c) In addition to complying with the provisions of this part, the
owner or operator of an affected facility may be required to obtain an
operating permit issued to stationary sources by an authorized State air
pollution control agency or by the Administrator of the U.S.
Environmental Protection Agency (EPA) pursuant to Title V of the Clean
Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more
information about obtaining an operating permit see part 70 of this
chapter.
(d) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant
in Elkton, Virginia. (1) This paragraph applies only to the
pharmaceutical manufacturing facility, commonly referred to as the
Stonewall Plant, located at Route 340 South, in Elkton, Virginia
(``site'').
(2) Except for compliance with 40 CFR 60.49b(u), the site shall have
the option of either complying directly with the requirements of this
part, or reducing the site-wide emissions caps in accordance with the
procedures set forth in a permit issued pursuant to 40 CFR 52.2454. If
the site chooses the option of reducing the site-wide emissions caps in
accordance with the procedures set forth in such permit, the
requirements of such permit shall apply in lieu of the otherwise
applicable requirements of this part.
(3) Notwithstanding the provisions of paragraph (d)(2) of this
section, for any provisions of this part except for Subpart Kb, the
owner/operator of the site shall comply with the applicable provisions
of this part if the Administrator determines that compliance with the
provisions of this part is necessary for achieving the objectives of the
regulation and the Administrator notifies the site in accordance with
the provisions of the permit issued pursuant to 40 CFR 52.2454.
[40 FR 53346, Nov. 17, 1975, as amended at 55 FR 51382, Dec. 13, 1990;
59 FR 12427, Mar. 16, 1994; 62 FR 52641, Oct. 8, 1997]
Sec. 60.2 Definitions.
The terms used in this part are defined in the Act or in this
section as follows:
Act means the Clean Air Act (42 U.S.C. 7401 et seq.)
Administrator means the Administrator of the Environmental
Protection Agency or his authorized representative.
Affected facility means, with reference to a stationary source, any
apparatus to which a standard is applicable.
Alternative method means any method of sampling and analyzing for an
air pollutant which is not a reference or equivalent method but which
has been demonstrated to the Administrator's satisfaction to, in
specific cases, produce results adequate for his determination of
compliance.
Approved permit program means a State permit program approved by the
Administrator as meeting the requirements of part 70 of this chapter or
a Federal permit program established in this chapter pursuant to Title V
of the Act (42 U.S.C. 7661).
Capital expenditure means an expenditure for a physical or
operational change to an existing facility which exceeds the product of
the applicable ``annual asset guideline repair allowance percentage''
specified in the latest edition of Internal Revenue Service (IRS)
Publication 534 and the existing facility's basis, as defined by section
1012 of the Internal Revenue Code. However, the total expenditure for a
physical or operational change to an existing facility must not be
reduced by any ``excluded additions'' as defined in IRS Publication 534,
as would be done for tax purposes.
Clean coal technology demonstration project means a project using
funds appropriated under the heading `Department of Energy-Clean Coal
Technology', up to a total amount of $2,500,000,000 for commercial
demonstrations of clean coal technology,
[[Page 23]]
or similar projects funded through appropriations for the Environmental
Protection Agency.
Commenced means, with respect to the definition of new source in
section 111(a)(2) of the Act, that an owner or operator has undertaken a
continuous program of construction or modification or that an owner or
operator has entered into a contractual obligation to undertake and
complete, within a reasonable time, a continuous program of construction
or modification.
Construction means fabrication, erection, or installation of an
affected facility.
Continuous monitoring system means the total equipment, required
under the emission monitoring sections in applicable subparts, used to
sample and condition (if applicable), to analyze, and to provide a
permanent record of emissions or process parameters.
Electric utility steam generating unit means any steam electric
generating unit that is constructed for the purpose of supplying more
than one-third of its potential electric output capacity and more than
25 MW electrical output to any utility power distribution system for
sale. Any steam supplied to a steam distribution system for the purpose
of providing steam to a steam-electric generator that would produce
electrical energy for sale is also considered in determining the
electrical energy output capacity of the affected facility.
Equivalent method means any method of sampling and analyzing for an
air pollutant which has been demonstrated to the Administrator's
satisfaction to have a consistent and quantitatively known relationship
to the reference method, under specified conditions.
Excess Emissions and Monitoring Systems Performance Report is a
report that must be submitted periodically by a source in order to
provide data on its compliance with stated emission limits and operating
parameters, and on the performance of its monitoring systems.
Existing facility means, with reference to a stationary source, any
apparatus of the type for which a standard is promulgated in this part,
and the construction or modification of which was commenced before the
date of proposal of that standard; or any apparatus which could be
altered in such a way as to be of that type.
Isokinetic sampling means sampling in which the linear velocity of
the gas entering the sampling nozzle is equal to that of the undisturbed
gas stream at the sample point.
Issuance of a part 70 permit will occur, if the State is the
permitting authority, in accordance with the requirements of part 70 of
this chapter and the applicable, approved State permit program. When the
EPA is the permitting authority, issuance of a Title V permit occurs
immediately after the EPA takes final action on the final permit.
Malfunction means any sudden, infrequent, and not reasonably
preventable failure of air pollution control equipment, process
equipment, or a process to operate in a normal or usual manner. Failures
that are caused in part by poor maintenance or careless operation are
not malfunctions.
Modification means any physical change in, or change in the method
of operation of, an existing facility which increases the amount of any
air pollutant (to which a standard applies) emitted into the atmosphere
by that facility or which results in the emission of any air pollutant
(to which a standard applies) into the atmosphere not previously
emitted.
Monitoring device means the total equipment, required under the
monitoring of operations sections in applicable subparts, used to
measure and record (if applicable) process parameters.
Nitrogen oxides means all oxides of nitrogen except nitrous oxide,
as measured by test methods set forth in this part.
One-hour period means any 60-minute period commencing on the hour.
Opacity means the degree to which emissions reduce the transmission
of light and obscure the view of an object in the background.
Owner or operator means any person who owns, leases, operates,
controls, or supervises an affected facility or a stationary source of
which an affected facility is a part.
Part 70 permit means any permit issued, renewed, or revised pursuant
to part 70 of this chapter.
[[Page 24]]
Particulate matter means any finely divided solid or liquid
material, other than uncombined water, as measured by the reference
methods specified under each applicable subpart, or an equivalent or
alternative method.
Permit program means a comprehensive State operating permit system
established pursuant to title V of the Act (42 U.S.C. 7661) and
regulations codified in part 70 of this chapter and applicable State
regulations, or a comprehensive Federal operating permit system
established pursuant to title V of the Act and regulations codified in
this chapter.
Permitting authority means:
(1) The State air pollution control agency, local agency, other
State agency, or other agency authorized by the Administrator to carry
out a permit program under part 70 of this chapter; or
(2) The Administrator, in the case of EPA-implemented permit
programs under title V of the Act (42 U.S.C. 7661).
Proportional sampling means sampling at a rate that produces a
constant ratio of sampling rate to stack gas flow rate.
Reactivation of a very clean coal-fired electric utility steam
generating unit means any physical change or change in the method of
operation associated with the commencement of commercial operations by a
coal-fired utility unit after a period of discontinued operation where
the unit:
(1) Has not been in operation for the two-year period prior to the
enactment of the Clean Air Act Amendments of 1990, and the emissions
from such unit continue to be carried in the permitting authority's
emissions inventory at the time of enactment;
(2) Was equipped prior to shut-down with a continuous system of
emissions control that achieves a removal efficiency for sulfur dioxide
of no less than 85 percent and a removal efficiency for particulates of
no less than 98 percent;
(3) Is equipped with low-NOx burners prior to the time of
commencement of operations following reactivation; and
(4) Is otherwise in compliance with the requirements of the Clean
Air Act.
Reference method means any method of sampling and analyzing for an
air pollutant as specified in the applicable subpart.
Repowering means replacement of an existing coal-fired boiler with
one of the following clean coal technologies: atmospheric or pressurized
fluidized bed combustion, integrated gasification combined cycle,
magnetohydrodynamics, direct and indirect coal-fired turbines,
integrated gasification fuel cells, or as determined by the
Administrator, in consultation with the Secretary of Energy, a
derivative of one or more of these technologies, and any other
technology capable of controlling multiple combustion emissions
simultaneously with improved boiler or generation efficiency and with
significantly greater waste reduction relative to the performance of
technology in widespread commercial use as of November 15, 1990.
Repowering shall also include any oil and/or gas-fired unit which has
been awarded clean coal technology demonstration funding as of January
1, 1991, by the Department of Energy.
Run means the net period of time during which an emission sample is
collected. Unless otherwise specified, a run may be either intermittent
or continuous within the limits of good engineering practice.
Shutdown means the cessation of operation of an affected facility
for any purpose.
Six-minute period means any one of the 10 equal parts of a one-hour
period.
Standard means a standard of performance proposed or promulgated
under this part.
Standard conditions means a temperature of 293 K (68F) and a
pressure of 101.3 kilopascals (29.92 in Hg).
Startup means the setting in operation of an affected facility for
any purpose.
State means all non-Federal authorities, including local agencies,
interstate associations, and State-wide programs, that have delegated
authority to implement: (1) The provisions of this part; and/or (2) the
permit program established under part 70 of this chapter. The term State
shall have its conventional meaning where clear from the context.
Stationary source means any building, structure, facility, or
installation which emits or may emit any air pollutant.
[[Page 25]]
Title V permit means any permit issued, renewed, or revised pursuant
to Federal or State regulations established to implement title V of the
Act (42 U.S.C. 7661). A title V permit issued by a State permitting
authority is called a part 70 permit in this part.
Volatile Organic Compound means any organic compound which
participates in atmospheric photochemical reactions; or which is
measured by a reference method, an equivalent method, an alternative
method, or which is determined by procedures specified under any
subpart.
[44 FR 55173, Sept. 25, 1979, as amended at 45 FR 5617, Jan. 23, 1980;
45 FR 85415, Dec. 24, 1980; 54 FR 6662, Feb. 14, 1989; 55 FR 51382, Dec.
13, 1990; 57 FR 32338, July 21, 1992; 59 FR 12427, Mar. 16, 1994]
Sec. 60.3 Units and abbreviations.
Used in this part are abbreviations and symbols of units of measure.
These are defined as follows:
(a) System International (SI) units of measure:
A--ampere
g--gram
Hz--hertz
J--joule
K--degree Kelvin
kg--kilogram
m--meter
m 3--cubic meter
mg--milligram--10- 3 gram
mm--millimeter--10- 3 meter
Mg--megagram--10 6 gram
mol--mole
N--newton
ng--nanogram--10- 9 gram
nm--nanometer--10- 9 meter
Pa--pascal
s--second
V--volt
W--watt
--ohm
g--microgram--10- 6 gram
(b) Other units of measure:
Btu--British thermal unit
deg.C--degree Celsius (centigrade)
cal--calorie
cfm--cubic feet per minute
cu ft--cubic feet
dcf--dry cubic feet
dcm--dry cubic meter
dscf--dry cubic feet at standard conditions
dscm--dry cubic meter at standard conditions
eq--equivalent
deg.F--degree Fahrenheit
ft--feet
gal--gallon
gr--grain
g-eq--gram equivalent
hr--hour
in--inch
k--1,000
l--liter
lpm--liter per minute
lb--pound
meq--milliequivalent
min--minute
ml--milliliter
mol. wt.--molecular weight
ppb--parts per billion
ppm--parts per million
psia--pounds per square inch absolute
psig--pounds per square inch gage
deg.R--degree Rankine
scf--cubic feet at standard conditions
scfh--cubic feet per hour at standard conditions
scm--cubic meter at standard conditions
sec--second
sq ft--square feet
std--at standard conditions
(c) Chemical nomenclature:
CdS--cadmium sulfide
CO--carbon monoxide
CO2--carbon dioxide
HCl--hydrochloric acid
Hg--mercury
H2O--water
H2S--hydrogen sulfide
H2SO4--sulfuric acid
N2--nitrogen
NO--nitric oxide
NO2--nitrogen dioxide
NOx--nitrogen oxides
O2--oxygen
SO2--sulfur dioxide
SO3--sulfur trioxide
SOx--sulfur oxides
(d) Miscellaneous:
A.S.T.M.--American Society for Testing and Materials
[42 FR 37000, July 19, 1977; 42 FR 38178, July 27, 1977]
Sec. 60.4 Address.
(a) All requests, reports, applications, submittals, and other
communications to the Administrator pursuant to this part shall be
submitted in duplicate to the appropriate Regional Office of the U.S.
Environmental Protection Agency to the attention of the Director of the
Division indicated in the following list of EPA Regional Offices.
Region I (Connecticut, Maine, Massachusetts, New Hampshire, Rhode
Island,
[[Page 26]]
Vermont), Director, Air Management Division, U.S. Environmental
Protection Agency, John F. Kennedy Federal Building, Boston, MA 02203.
Region II (New Jersey, New York, Puerto Rico, Virgin Islands), Director,
Air and Waste Management Division, U.S. Environmental Protection Agency,
Federal Office Building, 26 Federal Plaza (Foley Square), New York, NY
10278.
Region III (Delaware, District of Columbia, Maryland, Pennsylvania,
Virginia, West Virginia), Director, Air and Waste Management Division,
U.S. Environmental Protection Agency, Curtis Building, Sixth and Walnut
Streets, Philadelphia, PA 19106.
Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North
Carolina, South Carolina, Tennessee), Director, Air and Waste Management
Division, U.S. Environmental Protection Agency, 345 Courtland Street,
NE., Atlanta, GA 30365.
Region V (Illinois, Indiana, Michigan, Minnesota, Ohio, Wisconsin),
Director, Air and Radiation Division, U.S. Environmental Protection
Agency, 77 West Jackson Boulevard, Chicago, IL 60604-3590.
Region VI (Arkansas, Louisiana, New Mexico, Oklahoma, Texas); Director;
Air, Pesticides, and Toxics Division; U.S. Environmental Protection
Agency, 1445 Ross Avenue, Dallas, TX 75202.
Region VII (Iowa, Kansas, Missouri, Nebraska), Director, Air and Toxics
Division, U.S. Environmental Protection Agency, 726 Minnesota Avenue,
Kansas City, KS 66101.
Region VIII (Colorado, Montana, North Dakota, South Dakota, Utah,
Wyoming), Assistant Regional Administrator, Office of Enforcement,
Compliance and Environmental Justice, 999 18th Street, Suite 300,
Denver, CO 80222-2466.
Region IX (American Samoa, Arizona, California, Guam, Hawaii, Nevada),
Director, Air and Waste Management Division, U.S. Environmental
Protection Agency, 215 Fremont Street, San Francisco, CA 94105.
Region X (Alaska, Oregon, Idaho, Washington), Director, Air and Waste
Management Division, U.S. Environmental Protection Agency, 1200 Sixth
Avenue, Seattle, WA 98101.
(b) Section 111(c) directs the Administrator to delegate to each
State, when appropriate, the authority to implement and enforce
standards of performance for new stationary sources located in such
State. All information required to be submitted to EPA under paragraph
(a) of this section, must also be submitted to the appropriate State
Agency of any State to which this authority has been delegated
(provided, that each specific delegation may except sources from a
certain Federal or State reporting requirement). The appropriate mailing
address for those States whose delegation request has been approved is
as follows:
(A) [Reserved]
(B) State of Alabama, Air Pollution Control Division, Air Pollution
Control Commission, 645 S. McDonough Street, Montgomery, AL 36104.
(C) State of Alaska, Department of Environmental Conservation, Pouch
O, Juneau, AK 99811.
(D) Arizona:
Arizona Department of Health Services, 1740 West Adams Street, Phoenix,
AZ 85007.
Maricopa County Department of Health Services, Bureau of Air Pollution
Control, 1825 East Roosevelt Street, Phoenix, AZ 85006.
Pima County Health Department, Air Quality Control District, 151 West
Congress, Tucson, AZ 85701.
Pima County Air Pollution Control District, 151 West Congress Street,
Tucson, AZ 85701.
(1) The following table lists the specific source and pollutant
categories that have been delegated to the air pollution control
agencies in Arizona. A star (*) is used to indicate each category that
has been delegated.
[[Page 27]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.000
[[Page 28]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.001
(E) State of Arkansas: Chief, Division of Air Pollution Control,
Arkansas Department of Pollution Control and Ecology, 8001 National
Drive, P.O. Box 9583, Little Rock, AR 72209.
(F) California:
Amador County Air Pollution Control District, P.O. Box 430, 810 Court
Street, Jackson, CA 95642
Bay Area Air Pollution Control District, 939 Ellis Street, San
Francisco, CA 94109.
Butte County Air Pollution Control District, P.O. Box 1229, 316 Nelson
Avenue, Oroville, CA 95965
Calaveras County Air Pollution Control District, Government Center, El
Dorado Road, San Andreas, CA 95249
Colusa County Air Pollution Control District, 751 Fremont Street,
Colusa, CA 95952
El Dorado Air Pollution Control District, 330 Fair Lane, Placerville, CA
95667
Fresno County Air Pollution Control District, 1221 Fulton Mall, Fresno,
CA 93721
Glenn County Air Pollution Control District, P.O. Box 351, 720 North
Colusa Street, Willows, CA 95988
Great Basin Unified Air Pollution Control District, 157 Short Street,
Suite 6, Bishop, CA 93514
Imperial County Air Pollution Control District, County Services
Building, 939 West Main Street, El Centro, CA 92243
Kern County Air Pollution Control District, 1601 H Street, Suite 250,
Bakersfield, CA 93301
Kings County Air Pollution Control District, 330 Campus Drive, Hanford,
CA 93230
Lake County Air Pollution Control District, 255 North Forbes Street,
Lakeport, CA 95453
Lassen County Air Pollution Control District, 175 Russell Avenue,
Susanville, CA 96130
Madera County Air Pollution Control District, 135 W. Yosemite Avenue,
Madera, CA 93637.
Mariposa County Air Pollution Control District, Box 5, Mariposa, CA
95338
Mendocino County Air Pollution Control District, County Courthouse,
Ukiah, CA 95482.
Merced County Air Pollution Control District, P.O. Box 471, 240 East
15th Street, Merced, CA 95340
Modoc County Air Pollution Control District, 202 West 4th Street,
Alturas, CA 96101
Monterey Bay Unified Air Pollution Control, 1164 Monroe Street, Suite
10, Salinas, CA 93906
Nevada County Air Pollution Control District, H.E.W. Complex, Nevada
City, CA 95959
North Coast Unified Air Quality Management District, 5630 South
Broadway, Eureka, CA 95501
Northern Sonoma County Air Pollution Control District, 134 ``A'' Avenue,
Auburn, CA 95448
Placer County Air Pollution Control District, 11491 ``B'' Avenue,
Auburn, CA 95603
Plumas County Air Pollution Control District, P.O. Box 480, Quincy, CA
95971
Sacramento County Air Pollution Control District, 3701 Branch Center
Road, Sacramento, CA 95827.
[[Page 29]]
San Bernardino County Air Pollution Control District, 15579-8th,
Victorville, CA 92392
San Diego County Air Pollution Control District, 9150 Chesapeake Drive,
San Diego, CA 92123.
San Joaquin County Air Pollution Control District, 1601 E. Hazelton
Street (P.O. Box 2009) Stockton, CA 95201.
San Luis Obispo County Air Pollution Control District, P.O. Box 637, San
Luis Obispo, CA 93406
Santa Barbara County Air Pollution Control District, 315 Camino del
Rimedio, Santa Barbara, CA 93110
Shasta County Air Pollution Control District, 2650 Hospital Lane,
Redding, CA 96001
Sierra County Air Pollution Control District, P.O. Box 286, Downieville,
CA 95936
Siskiyou County Air Pollution Control District, 525 South Foothill
Drive, Yreka, CA 96097
South Coast Air Quality Management District, 9150 Flair Drive, El Monte,
CA 91731
Stanislaus County Air Pollution Control District, 1030 Scenic Drive,
Modesto, CA 95350
Sutter County Air Pollution Control District, Sutter County Office
Building, 142 Garden Highway, Yuba City, CA 95991
Tehama County Air Pollution Control District, P.O. Box 38, 1760 Walnut
Street, Red Bluff, CA 96080
Tulare County Air Pollution Control District, County Civic Center,
Visalia, CA 93277
Tuolumne County Air Pollution Control District, 9 North Washington
Street, Sonora, CA 95370
Ventura County Air Pollution Control District, 800 South Victoria
Avenue, Ventura, CA 93009
Yolo-Solano Air Pollution Control District, P.O. Box 1006, 323 First
Street, 5, Woodland, CA 95695
(1) The following table lists the specific source and pollutant
categories that have been delegated to the air pollution control
agencies in California. A star (*) is used to indicate each category
that has been delegated.
[[Page 30]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.002
[[Page 31]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.003
(G) State of Colorado, Department of Public Health and Environment,
4300 Cherry Creek Drive South, Denver, CO 80222-1530.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragraph (c) of this section.
(H) State of Connecticut, Bureau of Air Management, Department of
Environmental Protection, State Office Building, 165 Capitol Avenue,
Hartford, CT 06106.
(I) State of Delaware, Delaware Department of Natural Resources and
Environmental Control, 89 Kings Highway, P.O. Box 1401, Dover, DE 19901
(J) District of Columbia, Department of Consumer and Regulatory
Affairs, 5000 Overlook Avenue SW., Washington DC 20032.
(K) Bureau of Air Quality Management, Department of Environmental
Regulation, Twin Towers Office Building, 2600 Blair Stone Road,
Tallahassee, FL 32301.
(L) State of Georgia, Environmental Protection Division, Department
of Natural Resources, 270 Washington Street, SW., Atlanta, GA 30334.
(M) Hawaii Department of Health, 1250 Punchbowl Street, Honolulu, HI
96813
[[Page 32]]
Hawaii Department of Health (mailing address), Post Office Box 3378,
Honolulu, HI 96801
(N) State of Idaho, Department of Health and Welfare, Statehouse,
Boise, ID 83701.
(O) State of Illinois, Bureau of Air, Division of Air Pollution
Control, Illinois Environmental Protection Agency, 2200 Churchill Road,
Springfield, IL 62794-9276.
(P) State of Indiana, Indiana Department of Environmental
Management, 100 North Senate Avenue, P.O. Box 6015, Indianapolis,
Indiana 46206-6015.
(Q) State of Iowa: Iowa Department of Natural Resources,
Environmental Protection Division, Henry A. Wallace Building, 900 East
Grand, Des Moines, IO 50319.
(R) State of Kansas: Kansas Department of Health and Environment,
Bureau of Air Quality and Radiation Control, Forbes Field, Topeka, KS
66620.
(S) Division of Air Pollution Control, Department for Natural
Resources and Environmental Protection, U.S. 127, Frankfort, KY 40601.
(T) State of Louisiana: Program Administrator, Air Quality Division,
Louisiana Department of Environmental Quality, P.O. Box 44096, Baton
Rouge, LA 70804.
(U) State of Maine, Bureau of Air Quality Control, Department of
Environmental Protection, State House, Station No. 17, Augusta, ME
04333.
(V) State of Maryland: Bureau of Air Quality and Noise Control,
Maryland State Department of Health and Mental Hygiene, 201 West Preston
Street, Baltimore, MD 21201.
(W) Commonwealth of Massachusetts, Division of Air Quality Control,
Department of Environmental Protection, One Winter Street, 7th floor,
Boston, MA 02108.
(X) State of Michigan, Air Quality Division, Michigan Department of
Environmental Quality, P.O. Box 30260, Lansing, Michigan 48909.
(Y) Minnesota Pollution Control Agency, Division of Air Quality, 520
Lafayette Road, St. Paul, MN 55155.
(Z) Bureau of Pollution Control, Department of Natural Resources,
P.O. Box 10385, Jackson, MS 39209.
(AA) State of Missouri: Missouri Department of Natural Resources,
Division of Environmental Quality, P.O. Box 176, Jefferson City, MO
65102.
(BB) State of Montana, Department of Health and Environmental
Services, Air Quality Bureau, Cogswell Building, Helena, MT 59601.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragraph (c) of this section.
(CC) State of Nebraska, Nebraska Department of Environmental
Control, P.O. Box 94877, State House Station, Lincoln, NE 68509.
Lincoln-Lancaster County Health Department, Division of Environmental
Health, 2200 St. Marys Avenue, Lincoln, NE 68502
(DD) Nevada:
Nevada Department of Conservation and Natural Resources, Division of
Environmental Protection, 201 South Fall Street, Carson City, NV 89710.
Clark County County District Health Department, Air Pollution Control
Division, 625 Shadow Lane, Las Vegas, NV 89106.
Washoe County District Health Department, Division of Environmental
Protection, 10 Kirman Avenue, Reno, NV 89502.
(1) The following table lists the specific source and pollutant
categories that have been delegated to the air pollution control
agencies in Nevada. A star (*) is used to indicate each category that
has been delegated.
[[Page 33]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.004
[[Page 34]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.005
(EE) State of New Hampshire, Air Resources Division, Department of
Environmental Services, 64 North Main Street, Caller Box 2033, Concord,
NH 03302-2033.
(FF) State of New Jersey: New Jersey Department of Environmental
Protection, Division of Environmental Quality, Enforcement Element, John
Fitch Plaza, CN-027, Trenton, NJ 08625.
(1) The following table lists the specific source and pollutant
categories that have been delegated to the states in Region II. The (X)
symbol is used to indicate each category that has been delegated.
----------------------------------------------------------------------------------------------------------------
State
Subpart -----------------------------------------------------------------------
New Jersey New York Puerto Rico Virgin Islands
----------------------------------------------------------------------------------------------------------------
D Fossil-Fuel Fired Steam X............... X............... X............... X
Generators for Which
Construction Commenced
After August 17, 1971
(Steam Generators and
Lignite Fired Steam
Generators).
Da Electric Utility Steam X............... X...............
Generating Units for
Which Construction
Commenced After September
18, 1978.
Db Industrial-Commercial- X............... X............... X............... X
Institutional Steam
Generating Units.
E Incinerators.............. X............... X............... X............... X
F Portland Cement Plants.... X............... X............... X............... X
G Nitric Acid Plants........ X............... X............... X............... X
H Sulfuric Acid Plants...... X............... X............... X............... X
I Asphalt Concrete Plants... X............... X............... X............... X
J Petroleum Refineries--(All X............... X............... X............... X
Categories).
K Storage Vessels for X............... X............... X............... X
Petroleum Liquids
Constructed After June
11, 1973, and prior to
May 19, 1978.
Ka Storage Vessels for X............... X............... X...............
Petroleum Liquids
Constructed After May 18,
1978.
L Secondary Lead Smelters... X............... X............... X............... X
M Secondary Brass and Bronze X............... X............... X............... X
Ingot Production Plants.
N Iron and Steel Plants..... X............... X............... X............... X
O Sewage Treatment Plants... X............... X............... X............... X
P Primary Copper Smelters... X............... X............... X............... X
Q Primary Zinc Smelters..... X............... X............... X............... X
R Primary Lead Smelters..... X............... X............... X............... X
[[Page 35]]
S Primary Aluminum Reduction X............... X............... X............... X
Plants.
T Phosphate Fertilizer X............... X............... X............... X
Industry: Wet Process
Phosphoric Acid Plants.
U Phosphate Fertilizer X............... X............... X............... X
Industry: Superphosphoric
Acid Plants.
V Phosphate Fertilizer X............... X............... X............... X
Industry: Diammonium
Phosphate Plants.
W Phosphate Fertilizer X............... X............... X............... X
Industry: Triple
Superphosphate Plants.
X Phosphate Fertilizer X............... X............... X............... X
Industry: Granular Triple
Superphosphate.
Y Coal Preparation Plants... X............... X............... X............... X
Z Ferroally Production X............... X............... X............... X
Facilities.
AA Steel Plants: Electric Arc X............... X............... X............... X
Furnaces.
AAa Electric Arc Furnaces and X............... X............... X............... ................
Argon-Oxygen
Decarburization Vessels
in Steel Plants.
BB Kraft Pulp Mills.......... X............... X............... X............... ................
CC Glass Manufacturing Plants X............... X............... X............... ................
DD Grain Elevators........... X............... X............... X............... ................
EE Surface Coating of Metal X............... X............... X............... ................
Furniture.
GG Stationary Gas Turbines... X............... X............... X............... ................
HH Lime Plants............... X............... X............... X............... ................
KK Lead Acid Battery X............... X............... ................
Manufacturing Plants.
LL Metallic Mineral X............... X............... X............... ................
Processing Plants.
MM Automobile and Light-Duty X............... X............... .............. ................
Truck Surface Coating
Operations.
NN Phosphate Rock Plants..... X............... X...............
PP Ammonium Sulfate X............... X...............
Manufacturing Plants.
QQ Graphic Art Industry X............... X............... X............... X
Publication Rotogravure
Printing.
RR Pressure Sensitive Tape X............... X............... X............... ................
and Label Surface Coating
Operations.
SS Industrial Surface X............... X............... X............... ................
Coating: Large Appliances.
TT Metal Coil Surface Coating X............... X............... X............... ................
UU Asphalt Processing and X............... X............... X............... ................
Asphalt Roofing
Manufacture.
VV Equipment Leaks of X............... X............... ................
Volatile Organic
Compounds in Synthetic
Organic Chemical
Manufacturing Industry.
WW Beverage Can Surface X............... X............... X............... ................
Coating Industry.
XX Bulk Gasoline Terminals... X............... X............... X............... ................
FFF Flexible Vinyl and X............... X............... X............... ................
Urethane Coating and
Printing.
GGG Equipment Leaks of VOC in X............... X...............
Petroleum Refineries.
HHH Synthetic Fiber Production X............... X...............
Facilities.
JJJ Petroleum Dry Clearners... X............... X............... X............... ................
KKK Equipment Leaks of VOC
from Onshore Natural Gas
Processing Plants.
LLL Onshore Natural Gas X...............
Processing Plants; SO2
Emissions.
OOO Nonmetallic Mineral X............... X............... ................
Processing Plants.
PPP Wool Fiberglass Insulation X............... X............... ................
Manufacturing Plants.
----------------------------------------------------------------------------------------------------------------
(GG) State of New Mexico: Director, New Mexico Environmental
Improvement Division, Health and Environment Department, 1190 St.
Francis Drive, Santa Fe, NM 87503.
(i) The City of Albuquerque and Bernalillo County: Director, The
Albuquerque Environmental Health Department, The City of Albuquerque,
P.O. Box 1293, Albuquerque, NM 87103.
(HH) New York: New York State Department of Environmental
Conservation, 50 Wolf Road Albany, New York 12233, attention: Division
of Air Resources.
(II) North Carolina Environmental Management Commission, Department
of Natural and Economic Resources, Division of Environmental Management,
P.O. Box 27687, Raleigh, NC 27611. Attention: Air Quality Section.
(JJ) State of North Dakota, State Department of Health and
Consolidated Laboratories, Division of Environmental Engineering, State
Capitol, Bismarck, ND 58505.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragraph (c) of this section.
(KK) State of Ohio:
(i) Medina, Summit and Portage Counties; Director, Akron Regional
Air Quality Management District, 177 South Broadway, Akron, OH 44308.
(ii) Stark County: Air Pollution Control Division, 420 Market Avenue
North, Canton, Ohio 44702-3335.
(iii) Butler, Clermont, Hamilton, and Warren Counties: Air Program
Manager, Hamilton County Department of Environmental Services, 1632
Central Parkway, Cincinnati, Ohio 45210.
(iv) Cuyahoga County: Commissioner, Department of Public Health &
Welfare, Division of Air Pollution Control, 1925 Saint Clair, Cleveland,
Ohio 44114.
(v) Belmont, Carroll, Columbiana, Harrison, Jefferson, and Monroe
Counties: Director, North Ohio Valley Air Authority
[[Page 36]]
(NOVAA), 814 Adams Street, Steubenville, OH 43952.
(vi) Clark, Darke, Greene, Miami, Montgomery, and Preble Counties:
Director, Regional Air Pollution Control Agency (RAPCA) 451 West Third
Street, Dayton, Ohio 45402.
(vii) Lucas County and the City of Rossford (in Wood County):
Director, Toledo Environmental Services Agency, 26 Main Street, Toledo,
OH 43605.
(viii) Adams, Brown, Lawrence, and Scioto Counties; Engineer-
Director, Air Division, Portsmouth City Health Department, 740 Second
Street, Portsmouth, OH 45662.
(ix) Allen, Ashland, Auglaize, Crawford, Defiance, Erie, Fulton,
Hancock, Hardin, Henry, Huron, Marion, Mercer, Ottawa, Paulding, Putnam,
Richland, Sandusky, Seneca, Van Wert, Williams, Wood (except City of
Rossford), and Wyandot Counties: Ohio Environmental Protection Agency,
Northwest District Office, Air Pollution Control, 347 Dunbridge Rd.,
Bowling Green, Ohio 43402.
(x) Ashtabula, Holmes, Lorain, and Wayne Counties: Ohio
Environmental Protection Agency, Northeast District Office, Air
Pollution Unit, 2110 East Aurora Road, Twinsburg, OH 44087.
(xi) Athens, Coshocton, Gallia, Guernsey, Hocking, Jackson, Meigs,
Morgan, Muskingum, Noble, Perry, Pike, Ross, Tuscarawas, Vinton, and
Washington Counties: Ohio Environmental Protection Agency, Southeast
District Office, Air Pollution Unit, 2195 Front Street, Logan, OH 43138.
(xii) Champaign, Clinton, Highland, Logan, and Shelby Counties: Ohio
Environmental Protection Agency, Southwest District Office, Air
Pollution Unit, 401 East Fifth Street, Dayton, Ohio 45402-2911.
(xiii) Delaware, Fairfield, Fayette, Franklin, Knox, Licking,
Madison, Morrow, Pickaway, and Union Counties: Ohio Environmental
Protection Agency, Central District Office, Air Pollution Control, 3232
Alum Creek Drive, Columbus, Ohio, 43207-3417.
(xiv) Geauga and Lake Counties: Lake County General Health District,
Air Pollution Control, 105 Main Street, Painesville, OH 44077.
(xv) Mahoning and Trumbull Counties: Mahoning-Trumbull Air Pollution
Control Agency, 9 West Front Street, Youngstown, OH 44503.
(LL) State of Oklahoma, Oklahoma State Department of Health, Air
Quality Service, P.O. Box 53551, Oklahoma City, OK 73152.
(i) Oklahoma City and County: Director, Oklahoma City-County Health
Department, 921 Northeast 23rd Street, Oklahoma City, OK 73105.
(ii) Tulsa County: Tulsa City-County Health Department, 4616 East
Fifteenth Street, Tulsa, OK 74112.
(MM) State of Oregon, Department of Environmental Quality, Yeon
Building, 522 S.W. Fifth, Portland, OR 97204.
(i)--(viii) [Reserved]
(ix) Lane Regional Air Pollution Authority, 225 North Fifth, Suite
501, Springfield, OR 97477.
(NN) (a) City of Philadelphia: Philadelphia Department of Public
Health, Air Management Services, 500 S. Broad Street, Philadelphia, PA
19146.
(b) Commonwealth of Pennsylvania: Department of Environmental
Resources, Post Office Box 2063, Harrisburg, PA 17120.
(c) Allegheny County: Allegheny County Health Department, Bureau of
Air Pollution Control, 301 Thirty-ninth Street, Pittsburgh, PA 15201.
(OO) State of Rhode Island, Division of Air and Hazardous Materials,
Department of Environmental Management, 291 Promenade Street,
Providence, RI 02908.
(PP) State of South Carolina, Office of Environmental Quality
Control, Department of Health and Environmental Control, 2600 Bull
Street, Columbia, SC 29201.
(QQ) State of South Dakota, Air Quality Program, Department of
Environment and Natural Resources, Joe Foss Building, 523 East Capitol,
Pierre, SD 57501-3181.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragragh (c) of this section.
(RR) Division of Air Pollution Control, Tennessee Department of
Public Health, 256 Capitol Hill Building, Nashville, TN 37219.
Knox County Department of Air Pollution, City/County Building, Room
L222, 400 Main Avenue, Knoxville, TN 37902.
Air Pollution Control Bureau, Metropolitan Health Department, 311 23rd
Avenue North, Nashville, TN 37203.
(SS) State of Texas, Texas Air Control Board, 6330 Highway 290 East,
Austin, TX 78723.
(TT) State of Utah, Department of Health, Bureau of Air Quality, 288
North 1460 West, P.O. Box 16690, Salt Lake City, UT 84113--0690.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragraph (c) of this section.
(UU) State of Vermont, Air Pollution Control Division, Agency of
Natural Resources, Building 3 South, 103 South Main Street, Waterbury,
VT 05676.
(VV) Commonwealth of Virginia, Virginia State Air Pollution Control
Board, Room 1106, Ninth Street Office Building, Richmond, VA 23219.
(WW)(i) Washington: Washington Department of Ecology, Post Office
Box 47600, Olympia, WA 98504.
(ii) Benton-Franklin Counties Clean Air Authority (BFCCAA), 650
George Washington Way, Richland, WA 99352.
[[Page 37]]
(iii) Northwest Air Pollution Authority (NWAPA), 302 Pine Street,
#207, Mt. Vernon, WA 98273-3852.
(iv) Olympic Air Pollution Control Authority (OAPCA), 909 Sleater-
Kinney Rd. SE - Suite 1, Lacey, WA 98503.
(v) Puget Sound Air Pollution Control Authority (PSAPCA), 110 Union
Street, Suite 500, Seattle, WA 98101.
(vi) Southwest Air Pollution Control Authority (SWAPCA), 1308 N.E.
134th Street, Suite D, Vancouver, WA 98685-2747.
(vii) Spokane County Air Pollution Control Authority (SCAPCA), West
1101 College Avenue, Health Building, Room 403, Spokane, WA 99201.
(viii) [Reserved]
(ix) The following is a table indicating the delegation status of
the New Source Performance Standards for the State of Washington.
[[Page 38]]
Delegation of Authority--New Source Performance Standards State of Washington
--------------------------------------------------------------------------------------------------------------------------------------------------------
Subpart Description WDOE 1 BFCCAA 2 NWAPCA 3 OAPCA 4 PSAPCA 5 SWAPCA 6 SCAPCA 7
--------------------------------------------------------------------------------------------------------------------------------------------------------
A........................... General Provisions............. 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
D........................... Fossil-Fuel-Fired Steam 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Generators.
Da.......................... Electric Utility Steam 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Generating Units.
Db.......................... Industrial-Commercial- 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Institutional Steam Generating
Units.
Dc.......................... Small Industrial-Commercial- 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Institutional Steam Generating
Units.
E........................... Incinerators................... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Ea.......................... Municipal Waste Combustion..... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
F........................... Portland Cement Plants......... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
G........................... Nitric Acid Plants............. 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
H........................... Sulfuric Acid Plants........... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
I........................... Asphalt Concrete Plants........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
J........................... Petroleum Refineries........... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
K........................... Petroleum Liquid Storage 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Vessels 6/11/73-5/19/78.
Ka.......................... Petroleum Liquid Storage 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Vessels After 5/18/78-7/23/84.
Kb.......................... Volatile Organic Liquid Storage 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Vessels After 7/23/84.
L........................... Secondary Lead Smelters........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
M........................... Brass & Bronze Ingot Production 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plants.
N........................... Iron & Steel Plants: BOPF 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Particulate.
Na.......................... Iron & Steel Plants: BOPF, Hot 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Metal & Skimming Stations.
O........................... Sewage Treatment Plants........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
P........................... Primary Copper Smelters........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Q........................... Primary Zinc Smelters.......... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
R........................... Primary Lead Smelters.......... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
S........................... Primary Aluminum Reduction 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plants.
T........................... Wet Process Phosphoric Acid 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plants.
U........................... Superphosphoric Acid Plants.... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
V........................... Diammonium Phosphate Plants.... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
W........................... Triple Superphosphate Plants... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
X........................... Granular Triple Superphosphate 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Storage Facilities.
Y........................... Coal Preparation Plants........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Z........................... Ferroalloy Production 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Facilities.
AA.......................... Steel Plant Electric Arc 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Furnaces 10/21/74-8/17/83.
AAa......................... Steel Plant Electric Arc 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Furnaces & Argon-Oxygen
Decarburization Vessels after
8/7/83.
BB.......................... Kraft Pulp Mills............... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
CC.......................... Glass Manufacturing Plants..... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
DD.......................... Grain Elevators................ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
EE.......................... Surface Coating of Metal 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Furniture.
GG.......................... Stationary Gas Turbines........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
HH.......................... Lime Manufacturing Plants...... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
KK.......................... Lead-Acid Battery Manufacturing 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plant.
LL.......................... Metallic Mineral Processing 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plants.
MM.......................... Automobile & Light Duty Truck 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Surface Coating Operations.
NN.......................... Phosphate Rock Plants.......... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
PP.......................... Ammonium Sulfate Manufacture... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
QQ.......................... Graphic Arts Industry: 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Publication Rotogravure
Printing.
[[Page 39]]
RR.......................... Pressure Sensitive Tape & Label 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Surface Coating Operations.
SS.......................... Industrial Surface Coating: 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Large Appliances.
TT.......................... Metal Coil Surface Coating..... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
UU.......................... Asphalt Processing & Asphalt 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Roofing Manufacturer.
VV.......................... SOCMI Equipment Leaks (VOC).... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
WW.......................... Beverage Can Surface Coating 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Operations.
XX.......................... Bulk Gasoline Terminals........ 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
AAA......................... Residential Wood Heaters....... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
BBB......................... Rubber Tire Manufacturing...... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
DDD......................... Polymer Manufacturing Industry 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
(VOC).
FFF......................... Flexible Vinyl and Urethane 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Coating and Printing.
GGG......................... Equipment Leaks of VOC in 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Petroleum Refineries.
HHH......................... Synthetic Fiber Production 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Facilities.
III......................... VOC Emissions from SOCMI Air 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Oxidation Unit Processes.
JJJ......................... Petroleum Dry Cleaners......... 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
KKK......................... VOC Emissions from Onshore 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Natural Gas Production.
LLL......................... Onshore Natural Gas Production 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
(SO2).
NNN......................... VOC Emissions from SOCMI 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Distillation Facilities.
OOO......................... Nonmetallic Mineral Processing 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Plants.
PPP......................... Wool Fiberglass Insulation 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Manufacturing Plants.
QQQ......................... VOC Emissions from Petroleum 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Refinery Wastewater Systems.
SSS......................... Magnetic Tape Coating 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Facilities.
TTT......................... Surface Coating of Plastic 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Parts for Business Machines.
UUU......................... Calciners & Dryers In Mineral 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Industries.
VVV......................... Polymeric Coating of Support 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93 01/01/93
Substrates Facilities.
--------------------------------------------------------------------------------------------------------------------------------------------------------
1 WDOE--State of Washington Department of Ecology.
2 BFCCAA--Benton Franklin Counties Clean Air Authority.
3 NWAPCA--Northwest Air Pollution Control Authority.
4 OAPCA--Olympic Air Pollution Control Authority.
5 PSAPCA--Puget Sound Air Pollution Control Agency.
6 SWAPCA--Southwest Air Pollution Control Authority.
7 SCAPCA--Spokane County Air Pollution Control Authority.
[[Page 40]]
(XX) State of West Virginia: Air Pollution Control Commission, 1558
Washington Street East, Charleston, WV 25311.
(YY) Wisconsin--Wisconsin Department of Natural Resources, P.O. Box
7921, Madison, WI 53707.
(ZZ) State of Wyoming, Department of Environmental Quality, Air
Quality Division, Herschler Building, 122 West 25th Street, Cheyenne, WY
82002.
Editorial Note: For a table listing Region VIII's NSPS delegation
status, see paragraph (c) of this section.
(AAA) Territory of Guam: Guam Environmental Protection Agency, Post
Office Box 2999, Agana, Guam 96910.
(1) The following table lists the specific source and pollutant
categories that have been delegated to the air pollution control agency
in Guam. A star (*) is used to indicate each category that has been
delegated.
[[Page 41]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.006
[[Page 42]]
[GRAPHIC] [TIFF OMITTED] TC01JN92.007
(BBB) Commonwealth of Puerto Rico: Commonwealth of Puerto Rico
Environmental Quality Board, P.O. Box 11488, Santurce, PR 00910,
Attention: Air Quality Area Director (see table under
Sec. 60.4(b)(FF)(1)).
(CCC) U.S. Virgin Islands: U.S. Virgin Islands Department of
Conservation and Cultural Affairs, P.O. Box 578, Charlotte Amalie, St.
Thomas, VI 00801.
(c) The following is a table indicating the delegation status of New
Source Performance Standards for Region VIII.
Delegation Status of New Source Performance Standards
[(NSPS) for Region VIII]
----------------------------------------------------------------------------------------------------------------
Subpart CO MT\1\ ND SD\1\ UT\1\ WY
----------------------------------------------------------------------------------------------------------------
A--General Provisions......................... (*) (*) (*) (*) (*) (*)
D--Fossil Fuel Fired Steam Generators......... (*) (*) (*) (*) (*) (*)
Da--Electric Utility Steam Generators......... (*) (*) (*) (*) (*) (*)
Db--Industrial-Commercial--Institutional Steam (*) (*) (*) (*) (*) (*)
Generators...................................
Dc--Industrial-Commercial--Institutional Steam (*) (*) (*) (*) (*)
Generators...................................
E--Incinerators............................... (*) (*) (*) (*) (*) (*)
Ea--Municipal Waste Combustors................ (*) (*) (*) (*) (*) (*)
Eb--Large Municipal Waste Combustors.......... (*) (*)
Ec--Hospital/Medical/Infectious Waste (*) (*) (*)
Incinerators.................................
F--Portland Cement Plants..................... (*) (*) (*) (*) (*) (*)
G--Nitric Acid Plants......................... (*) (*) (*) (*) (*)
H--Sulfuric Acid Plants....................... (*) (*) (*) (*) (*)
I--Asphalt Concrete Plants.................... (*) (*) (*) (*) (*) (*)
J--Petroleum Refineries....................... (*) (*) (*) (*) (*)
K--Petroleum Storage Vessels (after 6/11/73 & (*) (*) (*) (*) (*) (*)
prior to.....................................
5/19/78)....................................
Ka--Petroleum Storage Vessels (after 5/18/78 & (*) (*) (*) (*) (*) (*)
prior to.....................................
7/23/84)....................................
Kb--Petroleum Storage Vessels (after 7/23/84). (*) (*) (*) (*) (*) (*)
L--Secondary Lead Smelters.................... (*) (*) (*) (*) (*)
M--Secondary Brass & Bronze Production Plants. (*) (*) (*) (*) (*)
N--Primary Emissions from Basic Oxygen Process (*) (*) (*) (*) (*)
Furnaces (after 6/11/73).....................
[[Page 43]]
Na--Secondary Emissions from Basic Oxygen (*) (*) (*) (*) (*)
Process Furnaces (after 1/20/83).............
O--Sewage Treatment Plants.................... (*) (*) (*) (*) (*) (*)
P--Primary Copper Smelters.................... (*) (*) (*) (*) (*)
Q--Primary Zinc Smelters...................... (*) (*) (*) (*) (*)
R--Primary Lead Smelters...................... (*) (*) (*) (*) (*)
S--Primary Aluminum Reduction Plants.......... (*) (*) (*) (*) (*)
T--Phosphate Fertilizer Industry: Wet Process (*) (*) (*) (*) (*)
Phosphoric Plants............................
U--Phosphate Fertilizer Industry: (*) (*) (*) (*) (*)
Superphosphoric Acid Plants..................
V--Phosphate Fertilizer Industry: Diammonium (*) (*) (*) (*) (*)
Phosphate Plants.............................
W--Phosphate Fertilizer Industry: Triple (*) (*) (*) (*) (*)
Superphosphate Plants........................
X--Phosphate Fertilizer Industry: Granular (*) (*) (*) (*) (*)
Triple Superphosphate Storage Facilities.....
Y--Coal Preparation Plants.................... (*) (*) (*) (*) (*) (*)
Z--Ferroalloy Production Facilities........... (*) (*) (*) (*) (*)
AA--Steel Plants: Electric Arc Furnaces (10/21/ (*) (*) (*) (*) (*)
74-8/17/83)..................................
AAa--Steel Plants: Electric Arc Furnaces and (*) (*) (*) (*) (*)
Argon-Oxygen Decarburization Vessels (after 8/
7/83)........................................
BB--Kraft Pulp Mills.......................... (*) (*) (*) (*) (*)
CC--Glass Manufacturing Plants................ (*) (*) (*) (*) (*)
DD--Grain Elevator............................ (*) (*) (*) (*) (*) (*)
EE--Surface Coating of Metal Furniture........ (*) (*) (*) (*) (*)
GG--Stationary Gas Turbines................... (*) (*) (*) (*) (*) (*)
HH--Lime Manufacturing Plants................. (*) (*) (*) (*) (*) (*)
KK--Lead-Acid Battery Manufacturing Plants.... (*) (*) (*) (*) (*)
LL--Metallic Mineral Processing Plants........ (*) (*) (*) (*) (*) (*)
MM--Automobile & Light Duty Truck Surface (*) (*) (*) (*) (*)
Coating Operations...........................
NN--Phosphate Rock Plants..................... (*) (*) (*) (*) (*)
PP--Ammonium Sulfate Manufacturing............ (*) (*) (*) (*) (*)
QQ--Graphic Arts Industry: Publication (*) (*) (*) (*) (*) (*)
Rotogravure Printing.........................
RR--Pressure Sensitive Tape & Label Surface (*) (*) (*) (*) (*) (*)
Coating......................................
SS--Industrial Surface Coating: Large (*) (*) (*) (*) (*)
Applications.................................
TT--Metal Coil Surface Coating................ (*) (*) (*) (*) (*)
UU--Asphalt Processing & Asphalt Roofing (*) (*) (*) (*) (*)
Manufacture..................................
VV--Synthetic Organic Chemicals Manufacturing: (*) (*) (*) (*) (*) (*)
Equipment Leaks of VOC.......................
WW--Beverage Can Surface Coating Industry..... (*) (*) (*) (*) (*)
XX--Bulk Gasoline Terminals................... (*) (*) (*) (*) (*) (*)
AAA--Residential Wood Heaters................. (*) (*) (*) (*) (*) (*)
BBB--Rubber Tires............................. (*) (*) (*) (*) (*)
DDD--VOC Emissions from Polymer Manufacturing (*) (*) (*) (*) (*)
Industry.....................................
FFF--Flexible Vinyl & Urethane Coating & (*) (*) (*) (*) (*)
Printing.....................................
GGG--Equipment Leaks of VOC in Petroleum (*) (*) (*) (*) (*)
Refineries...................................
HHH--Synthetic Fiber Production............... (*) (*) (*) (*) (*)
III--VOC Emissions from the Synthetic Organic (*) (*) (*) (*)
Chemical Manufacturing Industry Air Oxidation
Unit Processes...............................
JJJ--Petroleum Dry Cleaners................... (*) (*) (*) (*) (*) (*)
KKK--Equipment Leaks of VOC from Onshore (*) (*) (*) (*) (*)
Natural Gas Processing Plants................
LLL--Onshore Natural Gas Processing: SO2 (*) (*) (*) (*) (*)
Emissions....................................
NNN--VOC Emissions from the Synthetic Organic (*) (*) (*) (*) (*) (*)
Chemical Manufacturing Industry Distillation
Operations...................................
OOO--Nonmetallic Mineral Processing Plants.... (*) (*) (*) (*) (*) (*)
PPP--Wool Fiberglass Insulation Manufacturing (*) (*) (*) (*) (*)
Plants.......................................
QQQ--VOC Emissions from Petroleum Refinery (*) (*) (*) (*) (*)
Wastewater Systems...........................
[[Page 44]]
RRR--VOC Emissions from Synthetic Organic (*) (*) (*) (*) (*)
Chemical Manufacturing Industry (SOCMI)
Reactor Processes............................
SSS--Magnetic Tape Industry................... (*) (*) (*) (*) (*) (*)
TTT--Plastic Parts for Business Machine (*) (*) (*) (*) (*)
Coatings.....................................
UUU--Calciners and Dryers in Mineral (*) (*) (*) (*) (*)
Industries...................................
VVV--Polymeric Coating of Supporting (*) (*) (*) (*) (*)
Substrates...................................
WWW--Municipal Solid Waste Landfills.......... (*) (*) (*) (*) (*)
----------------------------------------------------------------------------------------------------------------
(*) Indicates approval of state regulation.
\1\ Indicates approval of New Source Performance Standards as part of the State Implementation Plan (SIP).
[40 FR 18169, Apr. 25, 1975]
Editorial Note: For Federal Register citations affecting Sec. 60.4
see the List of CFR Sections Affected which appears in the Finding Aids
section of the printed volume and on GPO Access.
Effective Date Note: At 66 FR 32554, June 15, 2001, Sec. 60.4 was
amended by revising the names and addresses listed for the EPA Region
VIII office in paragraph (a), the State of Montana in paragraph (b)(BB),
the State of North Dakota in paragraph (b)(JJ) and the State of Utah in
paragraph (b)(TT), and by amending the table entitled ``Delegation
Status of New Source Performance Standards [(NSPS) for Region VIII]'' in
paragraph (c) by revising the column heading for ``MT'' and the entries
for subparts ``Ec'', ``RRR'', ``UUU'' and ``WWW'', effective Aug. 14,
2001. For the convenience of the user, the revised text is set forth as
follows:
Sec. 60.4 Address.
(a) * * *
Region VIII (Colorado, Montana, North Dakota, South Dakota, Utah,
Wyoming) Assistant Regional Administrator, Office of Enforcement,
Compliance and Environmental Justice, 999 18th Street, Suite 300,
Denver, CO 80202-2466.
* * * * *
(b) * * *
(BB) State of Montana, Department of Environmental Quality, 1520 E.
6th Ave., PO Box 200901, Helena, MT 59620-0901.
Note: For a table listing Region VIII's NSPS delegation status, see
paragraph (c) of this section.
* * * * *
(JJ) State of North Dakota, Division of Air Quality, North Dakota
Department of Health, P.O. Box 5520, Bismarck, ND 58506-5520.
Note: For a table listing Region VIII's NSPS delegation status, see
paragraph (c) of this section.
* * * * *
(TT) State of Utah, Division of Air Quality, Department of
Environmental Quality, P.O. Box 144820, Salt Lake City, UT 84114-4820.
Note: For a table listing Region VIII's NSPS delegation status, see
paragraph (c) of this section.
* * * * *
(c) * * *
Delegation Status of New Source Performance Standards [(NPSP)] for Region VIII]
----------------------------------------------------------------------------------------------------------------
Subpart CO MT ND SD \1\ UT \1\ WY
----------------------------------------------------------------------------------------------------------------
* * * * * *
*
Ec-Hospital/Medical/Infectious Waste Incinerators............... (*) (*) (*) (*) ...... ......
* * * * * *
*
RRR--VOC Emissions from Synthetic Organic Chemistry (*) (*) (*) (*) (*) (*)
Manufacturing Industry (SOCMI) Reactor Processes...............
[[Page 45]]
* * * * * *
*
UUU--Calciners and Dryers in Mineral Industries................. (*) (*) (*) (*) (*) (*)
* * * * * *
*
WWW--Municipal Solid Waste Landfills............................ (*) (*) (*) (*) (*) (*)
----------------------------------------------------------------------------------------------------------------
(*) Indicates approval of State regulation.
\1\ Indicates approval of State regulation as part of the State Implementation Plan (SIP).
Sec. 60.5 Determination of construction or modification.
(a) When requested to do so by an owner or operator, the
Administrator will make a determination of whether action taken or
intended to be taken by such owner or operator constitutes construction
(including reconstruction) or modification or the commencement thereof
within the meaning of this part.
(b) The Administrator will respond to any request for a
determination under paragraph (a) of this section within 30 days of
receipt of such request.
[40 FR 58418, Dec. 16, 1975]
Sec. 60.6 Review of plans.
(a) When requested to do so by an owner or operator, the
Administrator will review plans for construction or modification for the
purpose of providing technical advice to the owner or operator.
(b)(1) A separate request shall be submitted for each construction
or modification project.
(2) Each request shall identify the location of such project, and be
accompanied by technical information describing the proposed nature,
size, design, and method of operation of each affected facility involved
in such project, including information on any equipment to be used for
measurement or control of emissions.
(c) Neither a request for plans review nor advice furnished by the
Administrator in response to such request shall (1) relieve an owner or
operator of legal responsibility for compliance with any provision of
this part or of any applicable State or local requirement, or (2)
prevent the Administrator from implementing or enforcing any provision
of this part or taking any other action authorized by the Act.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974]
Sec. 60.7 Notification and record keeping.
(a) Any owner or operator subject to the provisions of this part
shall furnish the Administrator written notification or, if acceptable
to both the Administrator and the owner or operator of a source,
electronic notification, as follows:
(1) A notification of the date construction (or reconstruction as
defined under Sec. 60.15) of an affected facility is commenced
postmarked no later than 30 days after such date. This requirement shall
not apply in the case of mass-produced facilities which are purchased in
completed form.
(2) [Reserved]
(3) A notification of the actual date of initial startup of an
affected facility postmarked within 15 days after such date.
(4) A notification of any physical or operational change to an
existing facility which may increase the emission rate of any air
pollutant to which a standard applies, unless that change is
specifically exempted under an applicable subpart or in Sec. 60.14(e).
This notice shall be postmarked 60 days or as soon as practicable before
the change is commenced and shall include information describing the
precise nature of the change, present and proposed emission control
systems, productive capacity of the facility before and after the
change, and the expected completion date of the change. The
Administrator may request additional relevant information subsequent to
this notice.
(5) A notification of the date upon which demonstration of the
continuous
[[Page 46]]
monitoring system performance commences in accordance with
Sec. 60.13(c). Notification shall be postmarked not less than 30 days
prior to such date.
(6) A notification of the anticipated date for conducting the
opacity observations required by Sec. 60.11(e)(1) of this part. The
notification shall also include, if appropriate, a request for the
Administrator to provide a visible emissions reader during a performance
test. The notification shall be postmarked not less than 30 days prior
to such date.
(7) A notification that continuous opacity monitoring system data
results will be used to determine compliance with the applicable opacity
standard during a performance test required by Sec. 60.8 in lieu of
Method 9 observation data as allowed by Sec. 60.11(e)(5) of this part.
This notification shall be postmarked not less than 30 days prior to the
date of the performance test.
(b) Any owner or operator subject to the provisions of this part
shall maintain records of the occurrence and duration of any startup,
shutdown, or malfunction in the operation of an affected facility; any
malfunction of the air pollution control equipment; or any periods
during which a continuous monitoring system or monitoring device is
inoperative.
(c) Each owner or operator required to install a continuous
monitoring device shall submit excess emissions and monitoring systems
performance report (excess emissions are defined in applicable subparts)
and-or summary report form (see paragraph (d) of this section) to the
Administrator semiannually, except when: more frequent reporting is
specifically required by an applicable subpart; or the Administrator, on
a case-by-case basis, determines that more frequent reporting is
necessary to accurately assess the compliance status of the source. All
reports shall be postmarked by the 30th day following the end of each
six-month period. Written reports of excess emissions shall include the
following information:
(1) The magnitude of excess emissions computed in accordance with
Sec. 60.13(h), any conversion factor(s) used, and the date and time of
commencement and completion of each time period of excess emissions. The
process operating time during the reporting period.
(2) Specific identification of each period of excess emissions that
occurs during startups, shutdowns, and malfunctions of the affected
facility. The nature and cause of any malfunction (if known), the
corrective action taken or preventative measures adopted.
(3) The date and time identifying each period during which the
continuous monitoring system was inoperative except for zero and span
checks and the nature of the system repairs or adjustments.
(4) When no excess emissions have occurred or the continuous
monitoring system(s) have not been inoperative, repaired, or adjusted,
such information shall be stated in the report.
(d) The summary report form shall contain the information and be in
the format shown in figure 1 unless otherwise specified by the
Administrator. One summary report form shall be submitted for each
pollutant monitored at each affected facility.
(1) If the total duration of excess emissions for the reporting
period is less than 1 percent of the total operating time for the
reporting period and CMS downtime for the reporting period is less than
5 percent of the total operating time for the reporting period, only the
summary report form shall be submitted and the excess emission report
described in Sec. 60.7(c) need not be submitted unless requested by the
Administrator.
(2) If the total duration of excess emissions for the reporting
period is 1 percent or greater of the total operating time for the
reporting period or the total CMS downtime for the reporting period is 5
percent or greater of the total operating time for the reporting period,
the summary report form and the excess emission report described in
Sec. 60.7(c) shall both be submitted.
Figure 1--Summary Report--Gaseous and Opacity Excess Emission and
Monitoring System Performance
Pollutant (Circle One--SO2/NOX/TRS/H2S/
CO/Opacity)
Reporting period dates: From __________ to __________
Company:
[[Page 47]]
Emission Limitation_____________________________________________________
Address:
Monitor Manufacturer and Model No.______________________________________
Date of Latest CMS Certification or Audit_______________________________
Process Unit(s) Description:
Total source operating time in reporting period \1\_____________________
------------------------------------------------------------------------
CMS performance
Emission data summary \1\ summary \1\
------------------------------------------------------------------------
1. Duration of excess 1. CMS downtime in
emissions in reporting reporting period due
period due to: to:
a. Startup/shutdown........ ........ a. Monitor ........
equipment
malfunctions.
b. Control equipment ........ b. Non-Monitor ........
problems. equipment
malfunctions.
c. Process problems........ ........ c. Quality ........
assurance
calibration.
d. Other known causes...... ........ d. Other known ........
causes.
e. Unknown causes.......... ........ e. Unknown causes.. ........
2. Total duration of excess ........ 2. Total CMS Downtime ........
emission.
3. Total duration of excess % \2\ 3. [Total CMS % \2\
emissions x (100) [Total Downtime] x (100)
source operating time]. [Total source
operating time].
------------------------------------------------------------------------
\1\ For opacity, record all times in minutes. For gases, record all
times in hours.
\2\ For the reporting period: If the total duration of excess emissions
is 1 percent or greater of the total operating time or the total CMS
downtime is 5 percent or greater of the total operating time, both the
summary report form and the excess emission report described in Sec.
60.7(c) shall be submitted.
On a separate page, describe any changes since last quarter in CMS,
process or controls. I certify that the information contained in this
report is true, accurate, and complete.
_______________________________________________________________________
Name
_______________________________________________________________________
Signature
_______________________________________________________________________
Title
_______________________________________________________________________
Date
(e)(1) Notwithstanding the frequency of reporting requirements
specified in paragraph (c) of this section, an owner or operator who is
required by an applicable subpart to submit excess emissions and
monitoring systems performance reports (and summary reports) on a
quarterly (or more frequent) basis may reduce the frequency of reporting
for that standard to semiannual if the following conditions are met:
(i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting
periods) the affected facility's excess emissions and monitoring systems
reports submitted to comply with a standard under this part continually
demonstrate that the facility is in compliance with the applicable
standard;
(ii) The owner or operator continues to comply with all
recordkeeping and monitoring requirements specified in this subpart and
the applicable standard; and
(iii) The Administrator does not object to a reduced frequency of
reporting for the affected facility, as provided in paragraph (e)(2) of
this section.
(2) The frequency of reporting of excess emissions and monitoring
systems performance (and summary) reports may be reduced only after the
owner or operator notifies the Administrator in writing of his or her
intention to make such a change and the Administrator does not object to
the intended change. In deciding whether to approve a reduced frequency
of reporting, the Administrator may review information concerning the
source's entire previous performance history during the required
recordkeeping period prior to the intended change, including performance
test results, monitoring data, and evaluations of an owner or operator's
conformance with operation and maintenance requirements. Such
information may be used by the Administrator to make a judgment about
the source's potential for noncompliance in the future. If the
Administrator disapproves the owner or operator's request to reduce the
frequency of reporting, the Administrator will notify the owner or
operator in writing within 45 days after receiving notice of the owner
or operator's intention. The notification from the Administrator to the
owner or operator will specify the grounds on which the disapproval is
based. In the absence of a notice of disapproval within 45 days,
approval is automatically granted.
(3) As soon as monitoring data indicate that the affected facility
is not in
[[Page 48]]
compliance with any emission limitation or operating parameter specified
in the applicable standard, the frequency of reporting shall revert to
the frequency specified in the applicable standard, and the owner or
operator shall submit an excess emissions and monitoring systems
performance report (and summary report, if required) at the next
appropriate reporting period following the noncomplying event. After
demonstrating compliance with the applicable standard for another full
year, the owner or operator may again request approval from the
Administrator to reduce the frequency of reporting for that standard as
provided for in paragraphs (e)(1) and (e)(2) of this section.
(f) Any owner or operator subject to the provisions of this part
shall maintain a file of all measurements, including continuous
monitoring system, monitoring device, and performance testing
measurements; all continuous monitoring system performance evaluations;
all continuous monitoring system or monitoring device calibration
checks; adjustments and maintenance performed on these systems or
devices; and all other information required by this part recorded in a
permanent form suitable for inspection. The file shall be retained for
at least two years following the date of such measurements, maintenance,
reports, and records, except as follows:
(1) This paragraph applies to owners or operators required to
install a continuous emissions monitoring system (CEMS) where the CEMS
installed is automated, and where the calculated data averages do not
exclude periods of CEMS breakdown or malfunction. An automated CEMS
records and reduces the measured data to the form of the pollutant
emission standard through the use of a computerized data acquisition
system. In lieu of maintaining a file of all CEMS subhourly measurements
as required under paragraph (f) of this section, the owner or operator
shall retain the most recent consecutive three averaging periods of
subhourly measurements and a file that contains a hard copy of the data
acquisition system algorithm used to reduce the measured data into the
reportable form of the standard.
(2) This paragraph applies to owners or operators required to
install a CEMS where the measured data is manually reduced to obtain the
reportable form of the standard, and where the calculated data averages
do not exclude periods of CEMS breakdown or malfunction. In lieu of
maintaining a file of all CEMS subhourly measurements as required under
paragraph (f) of this section, the owner or operator shall retain all
subhourly measurements for the most recent reporting period. The
subhourly measurements shall be retained for 120 days from the date of
the most recent summary or excess emission report submitted to the
Administrator.
(3) The Administrator or delegated authority, upon notification to
the source, may require the owner or operator to maintain all
measurements as required by paragraph (f) of this section, if the
Administrator or the delegated authority determines these records are
required to more accurately assess the compliance status of the affected
source.
(g) If notification substantially similar to that in paragraph (a)
of this section is required by any other State or local agency, sending
the Administrator a copy of that notification will satisfy the
requirements of paragraph (a) of this section.
(h) Individual subparts of this part may include specific provisions
which clarify or make inapplicable the provisions set forth in this
section.
[36 FR 24877, Dec. 28, 1971, as amended at 40 FR 46254, Oct. 6, 1975; 40
FR 58418, Dec. 16, 1975; 45 FR 5617, Jan. 23, 1980; 48 FR 48335, Oct.
18, 1983; 50 FR 53113, Dec. 27, 1985; 52 FR 9781, Mar. 26, 1987; 55 FR
51382, Dec. 13, 1990; 59 FR 12428, Mar. 16, 1994; 59 FR 47265, Sep. 15,
1994; 64 FR 7463, Feb. 12, 1999]
Sec. 60.8 Performance tests.
(a) Within 60 days after achieving the maximum production rate at
which the affected facility will be operated, but not later than 180
days after initial startup of such facility and at such other times as
may be required by the Administrator under section 114 of the Act, the
owner or operator of such facility shall conduct performance test(s)
[[Page 49]]
and furnish the Administrator a written report of the results of such
performance test(s).
(b) Performance tests shall be conducted and data reduced in
accordance with the test methods and procedures contained in each
applicable subpart unless the Administrator (1) specifies or approves,
in specific cases, the use of a reference method with minor changes in
methodology, (2) approves the use of an equivalent method, (3) approves
the use of an alternative method the results of which he has determined
to be adequate for indicating whether a specific source is in
compliance, (4) waives the requirement for performance tests because the
owner or operator of a source has demonstrated by other means to the
Administrator's satisfaction that the affected facility is in compliance
with the standard, or (5) approves shorter sampling times and smaller
sample volumes when necessitated by process variables or other factors.
Nothing in this paragraph shall be construed to abrogate the
Administrator's authority to require testing under section 114 of the
Act.
(c) Performance tests shall be conducted under such conditions as
the Administrator shall specify to the plant operator based on
representative performance of the affected facility. The owner or
operator shall make available to the Administrator such records as may
be necessary to determine the conditions of the performance tests.
Operations during periods of startup, shutdown, and malfunction shall
not constitute representative conditions for the purpose of a
performance test nor shall emissions in excess of the level of the
applicable emission limit during periods of startup, shutdown, and
malfunction be considered a violation of the applicable emission limit
unless otherwise specified in the applicable standard.
(d) The owner or operator of an affected facility shall provide the
Administrator at least 30 days prior notice of any performance test,
except as specified under other subparts, to afford the Administrator
the opportunity to have an observer present. If after 30 days notice for
an initially scheduled performance test, there is a delay (due to
operational problems, etc.) in conducting the scheduled performance
test, the owner or operator of an affected facility shall notify the
Administrator (or delegated State or local agency) as soon as possible
of any delay in the original test date, either by providing at least 7
days prior notice of the rescheduled date of the performance test, or by
arranging a rescheduled date with the Administrator (or delegated State
or local agency) by mutual agreement.
(e) The owner or operator of an affected facility shall provide, or
cause to be provided, performance testing facilities as follows:
(1) Sampling ports adequate for test methods applicable to such
facility. This includes (i) constructing the air pollution control
system such that volumetric flow rates and pollutant emission rates can
be accurately determined by applicable test methods and procedures and
(ii) providing a stack or duct free of cyclonic flow during performance
tests, as demonstrated by applicable test methods and procedures.
(2) Safe sampling platform(s).
(3) Safe access to sampling platform(s).
(4) Utilities for sampling and testing equipment.
(f) Unless otherwise specified in the applicable subpart, each
performance test shall consist of three separate runs using the
applicable test method. Each run shall be conducted for the time and
under the conditions specified in the applicable standard. For the
purpose of determining compliance with an applicable standard, the
arithmetic means of results of the three runs shall apply. In the event
that a sample is accidentally lost or conditions occur in which one of
the three runs must be discontinued because of forced shutdown, failure
of an irreplaceable portion of the sample train, extreme meteorological
conditions, or other circumstances, beyond the owner or operator's
control, compliance may, upon the Administrator's approval, be
determined using the arithmetic mean of the results of the two other
runs.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974; 42
FR 57126, Nov. 1, 1977; 44 FR 33612, June 11, 1979; 54 FR 6662, Feb. 14,
1989; 54 FR 21344, May 17, 1989; 64 FR 7463, Feb. 12, 1999]
[[Page 50]]
Sec. 60.9 Availability of information.
The availability to the public of information provided to, or
otherwise obtained by, the Administrator under this part shall be
governed by part 2 of this chapter. (Information submitted voluntarily
to the Administrator for the purposes of Secs. 60.5 and 60.6 is governed
by Secs. 2.201 through 2.213 of this chapter and not by Sec. 2.301 of
this chapter.)
Sec. 60.10 State authority.
The provisions of this part shall not be construed in any manner to
preclude any State or political subdivision thereof from:
(a) Adopting and enforcing any emission standard or limitation
applicable to an affected facility, provided that such emission standard
or limitation is not less stringent than the standard applicable to such
facility.
(b) Requiring the owner or operator of an affected facility to
obtain permits, licenses, or approvals prior to initiating construction,
modification, or operation of such facility.
Sec. 60.11 Compliance with standards and maintenance requirements.
(a) Compliance with standards in this part, other than opacity
standards, shall be determined in accordance with performance tests
established by Sec. 60.8, unless otherwise specified in the applicable
standard.
(b) Compliance with opacity standards in this part shall be
determined by conducting observations in accordance with Method 9 in
appendix A of this part, any alternative method that is approved by the
Administrator, or as provided in paragraph (e)(5) of this section. For
purposes of determining initial compliance, the minimum total time of
observations shall be 3 hours (30 6-minute averages) for the performance
test or other set of observations (meaning those fugitive-type emission
sources subject only to an opacity standard).
(c) The opacity standards set forth in this part shall apply at all
times except during periods of startup, shutdown, malfunction, and as
otherwise provided in the applicable standard.
(d) At all times, including periods of startup, shutdown, and
malfunction, owners and operators shall, to the extent practicable,
maintain and operate any affected facility including associated air
pollution control equipment in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of
whether acceptable operating and maintenance procedures are being used
will be based on information available to the Administrator which may
include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and
inspection of the source.
(e)(1) For the purpose of demonstrating initial compliance, opacity
observations shall be conducted concurrently with the initial
performance test required in Sec. 60.8 unless one of the following
conditions apply. If no performance test under Sec. 60.8 is required,
then opacity observations shall be conducted within 60 days after
achieving the maximum production rate at which the affected facility
will be operated but no later than 180 days after initial startup of the
facility. If visibility or other conditions prevent the opacity
observations from being conducted concurrently with the initial
performance test required under Sec. 60.8, the source owner or operator
shall reschedule the opacity observations as soon after the initial
performance test as possible, but not later than 30 days thereafter, and
shall advise the Administrator of the rescheduled date. In these cases,
the 30-day prior notification to the Administrator required in
Sec. 60.7(a)(6) shall be waived. The rescheduled opacity observations
shall be conducted (to the extent possible) under the same operating
conditions that existed during the initial performance test conducted
under Sec. 60.8. The visible emissions observer shall determine whether
visibility or other conditions prevent the opacity observations from
being made concurrently with the initial performance test in accordance
with procedures contained in Method 9 of appendix B of this part.
Opacity readings of portions of plumes which contain condensed,
uncombined water vapor shall not be used for purposes of determing
compliance with opacity standards. The owner or operator of an affected
facility shall make available,
[[Page 51]]
upon request by the Administrator, such records as may be necessary to
determine the conditions under which the visual observations were made
and shall provide evidence indicating proof of current visible observer
emission certification. Except as provided in paragraph (e)(5) of this
section, the results of continuous monitoring by transmissometer which
indicate that the opacity at the time visual observations were made was
not in excess of the standard are probative but not conclusive evidence
of the actual opacity of an emission, provided that the source shall
meet the burden of proving that the instrument used meets (at the time
of the alleged violation) Performance Specification 1 in appendix B of
this part, has been properly maintained and (at the time of the alleged
violation) that the resulting data have not been altered in any way.
(2) Except as provided in paragraph (e)(3) of this section, the
owner or operator of an affected facility to which an opacity standard
in this part applies shall conduct opacity observations in accordance
with paragraph (b) of this section, shall record the opacity of
emissions, and shall report to the Administrator the opacity results
along with the results of the initial performance test required under
Sec. 60.8. The inability of an owner or operator to secure a visible
emissions observer shall not be considered a reason for not conducting
the opacity observations concurrent with the initial performance test.
(3) The owner or operator of an affected facility to which an
opacity standard in this part applies may request the Administrator to
determine and to record the opacity of emissions from the affected
facility during the initial performance test and at such times as may be
required. The owner or operator of the affected facility shall report
the opacity results. Any request to the Administrator to determine and
to record the opacity of emissions from an affected facility shall be
included in the notification required in Sec. 60.7(a)(6). If, for some
reason, the Administrator cannot determine and record the opacity of
emissions from the affected facility during the performance test, then
the provisions of paragraph (e)(1) of this section shall apply.
(4) An owner or operator of an affected facility using a continuous
opacity monitor (transmissometer) shall record the monitoring data
produced during the initial performance test required by Sec. 60.8 and
shall furnish the Administrator a written report of the monitoring
results along with Method 9 and Sec. 60.8 performance test results.
(5) An owner or operator of an affected facility subject to an
opacity standard may submit, for compliance purposes, continuous opacity
monitoring system (COMS) data results produced during any performance
test required under Sec. 60.8 in lieu of Method 9 observation data. If
an owner or operator elects to submit COMS data for compliance with the
opacity standard, he shall notify the Administrator of that decision, in
writing, at least 30 days before any performance test required under
Sec. 60.8 is conducted. Once the owner or operator of an affected
facility has notified the Administrator to that effect, the COMS data
results will be used to determine opacity compliance during subsequent
tests required under Sec. 60.8 until the owner or operator notifies the
Administrator, in writing, to the contrary. For the purpose of
determining compliance with the opacity standard during a performance
test required under Sec. 60.8 using COMS data, the minimum total time of
COMS data collection shall be averages of all 6-minute continuous
periods within the duration of the mass emission performance test.
Results of the COMS opacity determinations shall be submitted along with
the results of the performance test required under Sec. 60.8. The owner
or operator of an affected facility using a COMS for compliance purposes
is responsible for demonstrating that the COMS meets the requirements
specified in Sec. 60.13(c) of this part, that the COMS has been properly
maintained and operated, and that the resulting data have not been
altered in any way. If COMS data results are submitted for compliance
with the opacity standard for a period of time during which Method 9
data indicates noncompliance, the Method 9 data will be used to
determine compliance with the opacity standard.
[[Page 52]]
(6) Upon receipt from an owner or operator of the written reports of
the results of the performance tests required by Sec. 60.8, the opacity
observation results and observer certification required by
Sec. 60.11(e)(1), and the COMS results, if applicable, the Administrator
will make a finding concerning compliance with opacity and other
applicable standards. If COMS data results are used to comply with an
opacity standard, only those results are required to be submitted along
with the performance test results required by Sec. 60.8. If the
Administrator finds that an affected facility is in compliance with all
applicable standards for which performance tests are conducted in
accordance with Sec. 60.8 of this part but during the time such
performance tests are being conducted fails to meet any applicable
opacity standard, he shall notify the owner or operator and advise him
that he may petition the Administrator within 10 days of receipt of
notification to make appropriate adjustment to the opacity standard for
the affected facility.
(7) The Administrator will grant such a petition upon a
demonstration by the owner or operator that the affected facility and
associated air pollution control equipment was operated and maintained
in a manner to minimize the opacity of emissions during the performance
tests; that the performance tests were performed under the conditions
established by the Administrator; and that the affected facility and
associated air pollution control equipment were incapable of being
adjusted or operated to meet the applicable opacity standard.
(8) The Administrator will establish an opacity standard for the
affected facility meeting the above requirements at a level at which the
source will be able, as indicated by the performance and opacity tests,
to meet the opacity standard at all times during which the source is
meeting the mass or concentration emission standard. The Administrator
will promulgate the new opacity standard in the Federal Register.
(f) Special provisions set forth under an applicable subpart shall
supersede any conflicting provisions in paragraphs (a) through (e) of
this section.
(g) For the purpose of submitting compliance certifications or
establishing whether or not a person has violated or is in violation of
any standard in this part, nothing in this part shall preclude the use,
including the exclusive use, of any credible evidence or information,
relevant to whether a source would have been in compliance with
applicable requirements if the appropriate performance or compliance
test or procedure had been performed.
[38 FR 28565, Oct. 15, 1973, as amended at 39 FR 39873, Nov. 12, 1974;
43 FR 8800, Mar. 3, 1978; 45 FR 23379, Apr. 4, 1980; 48 FR 48335, Oct.
18, 1983; 50 FR 53113, Dec. 27, 1985; 51 FR 1790, Jan. 15, 1986; 52 FR
9781, Mar. 26, 1987; 62 FR 8328, Feb. 24, 1997; 65 FR 61749, Oct. 17,
2000]
Sec. 60.12 Circumvention.
No owner or operator subject to the provisions of this part shall
build, erect, install, or use any article, machine, equipment or
process, the use of which conceals an emission which would otherwise
constitute a violation of an applicable standard. Such concealment
includes, but is not limited to, the use of gaseous diluents to achieve
compliance with an opacity standard or with a standard which is based on
the concentration of a pollutant in the gases discharged to the
atmosphere.
[39 FR 9314, Mar. 8, 1974]
Sec. 60.13 Monitoring requirements.
(a) For the purposes of this section, all continuous monitoring
systems required under applicable subparts shall be subject to the
provisions of this section upon promulgation of performance
specifications for continuous monitoring systems under appendix B to
this part and, if the continuous monitoring system is used to
demonstrate compliance with emission limits on a continuous basis,
appendix F to this part, unless otherwise specified in an applicable
subpart or by the Administrator. Appendix F is applicable December 4,
1987.
(b) All continuous monitoring systems and monitoring devices shall
be installed and operational prior to conducting performance tests under
Sec. 60.8. Verification of operational status
[[Page 53]]
shall, as a minimum, include completion of the manufacturer's written
requirements or recommendations for installation, operation, and
calibration of the device.
(c) If the owner or operator of an affected facility elects to
submit continous opacity monitoring system (COMS) data for compliance
with the opacity standard as provided under Sec. 60.11(e)(5), he shall
conduct a performance evaluation of the COMS as specified in Performance
Specification 1, appendix B, of this part before the performance test
required under Sec. 60.8 is conducted. Otherwise, the owner or operator
of an affected facility shall conduct a performance evaluation of the
COMS or continuous emission monitoring system (CEMS) during any
performance test required under Sec. 60.8 or within 30 days thereafter
in accordance with the applicable performance specification in appendix
B of this part, The owner or operator of an affected facility shall
conduct COMS or CEMS performance evaluations at such other times as may
be required by the Administrator under section 114 of the Act.
(1) The owner or operator of an affected facility using a COMS to
determine opacity compliance during any performance test required under
Sec. 60.8 and as described in Sec. 60.11(e)(5) shall furnish the
Administrator two or, upon request, more copies of a written report of
the results of the COMS performance evaluation described in paragraph
(c) of this section at least 10 days before the performance test
required under Sec. 60.8 is conducted.
(2) Except as provided in paragraph (c)(1) of this section, the
owner or operator of an affected facility shall furnish the
Administrator within 60 days of completion two or, upon request, more
copies of a written report of the results of the performance evaluation.
(d)(1) Owners and operators of a CEMS installed in accordance with
the provisions of this part, must automatically check the zero (or low
level value between 0 and 20 percent of span value) and span (50 to 100
percent of span value) calibration drifts at least once daily in
accordance with a written procedure. The zero and span must, as a
minimum, be adjusted whenever either the 24-hour zero drift or the 24-
hour span drift exceeds two times the limit of the applicable
performance specification in appendix B of this part. The system must
allow the amount of the excess zero and span drift to be recorded and
quantified whenever specified. Owners and operators of a COMS installed
in accordance with the provisions of this part, must automatically,
intrinsic to the opacity monitor, check the zero and upscale (span)
calibration drifts at least once daily. For a particular COMS, the
acceptable range of zero and upscale calibration materials is as defined
in the applicable version of PS-1 in appendix B of this part. For
continuous monitoring systems measuring opacity of emissions not using
automatic zero adjustments, the optical surfaces exposed to the effluent
gases shall be cleaned prior to performing the zero and span drift
adjustments. For systems using automatic zero adjustments, the optical
surfaces shall be cleaned when the cumulative automatic zero
compensation exceeds 4 percent opacity.
(2) Unless otherwise approved by the Administrator, the following
procedures must be followed for a COMS. Minimum procedures must include
an automated method for producing a simulated zero opacity condition and
an upscale opacity condition using a certified neutral density filter or
other related technique to produce a known obstruction of the light
beam. Such procedures must provide a system check of all active analyzer
internal optics with power or curvature, all active electronic circuitry
including the light source and photodetector assembly, and electronic or
electro-mechanical systems and hardware and or software used during
normal measurement operation.
(e) Except for system breakdowns, repairs, calibration checks, and
zero and span adjustments required under paragraph (d) of this section,
all continuous monitoring systems shall be in continuous operation and
shall meet minimum frequency of operation requirements as follows:
(1) All continuous monitoring systems referenced by paragraph (c) of
this section for measuring opacity of emissions shall complete a minimum
of
[[Page 54]]
one cycle of sampling and analyzing for each successive 10-second period
and one cycle of data recording for each successive 6-minute period.
(2) All continuous monitoring systems referenced by paragraph (c) of
this section for measuring emissions, except opacity, shall complete a
minimum of one cycle of operation (sampling, analyzing, and data
recording) for each successive 15-minute period.
(f) All continuous monitoring systems or monitoring devices shall be
installed such that representative measurements of emissions or process
parameters from the affected facility are obtained. Additional
procedures for location of continuous monitoring systems contained in
the applicable Performance Specifications of appendix B of this part
shall be used.
(g)(1) When more than one continuous monitoring system is used to
measure the emissions from only one affected facility (e.g., multiple
breechings, multiple outlets), the owner or operator shall report the
results as required from each continuous monitoring system. When the
effluent from one affected facility is released to the atmosphere
through more than one point, the owner or operator shall install an
applicable continuous monitoring system on each separate effluent unless
installation of fewer systems is approved by the Administrator.
(2) When the effluents from two or more affected facilities subject
to the same opacity standard are combined before being released to the
atmosphere, the owner or operator may either install a continuous
opacity monitoring system at a location monitoring the combined effluent
or install an opacity combiner system comprised of opacity and flow
monitoring systems on each stream, and shall report as per Sec. 60.7(c)
on the combined effluent. When the affected facilities are not subject
to the same opacity standard, the owner or operator shall report the
results as per Sec. 60.7(c) on the combined effluent against the most
stringent opacity standard applicable, except for documented periods of
shutdown of the affected facility, subject to the most stringent opacity
standard. During such times, the next most stringent opacity standard
shall apply.
(3) When the effluents from two or more affected facilities subject
to the same emissions standard, other than opacity, are combined before
being released to the atmosphere, the owner or operator may install
applicable continuous emission monitoring systems on each effluent or on
the combined effluent. The owner or operator may report the results as
required for each affected facility or for the combined effluent. When
the affected facilities are not subject to the same emissions standard,
separate continuous emission monitoring systems shall be installed on
each effluent and the owner or operator shall report as required for
each affected facility.
(h) Owners or operators of all continuous monitoring systems for
measurement of opacity shall reduce all data to 6-minute averages and
for continuous monitoring systems other than opacity to 1-hour averages
for time periods as defined in Sec. 60.2. Six-minute opacity averages
shall be calculated from 36 or more data points equally spaced over each
6-minute period. For continuous monitoring systems other than opacity,
1-hour averages shall be computed from four or more data points equally
spaced over each 1-hour period. Data recorded during periods of
continuous system breakdown, repair, calibration checks, and zero and
span adjustments shall not be included in the data averages computed
under this paragraph. For owners and operators complying with the
requirements in Sec. 60.7(f) (1) or (2), data averages must include any
data recorded during periods of monitor breakdown or malfunction. An
arithmetic or integrated average of all data may be used. The data may
be recorded in reduced or nonreduced form (e.g., ppm pollutant and
percent O2 or ng/J of pollutant). All excess emissions shall
be converted into units of the standard using the applicable conversion
procedures specified in subparts. After conversion into units of the
standard, the data may be rounded to the same number of significant
digits as used in the applicable subparts to specify the emission limit
(e.g., rounded to the nearest 1 percent opacity).
(i) After receipt and consideration of written application, the
Administrator
[[Page 55]]
may approve alternatives to any monitoring procedures or requirements of
this part including, but not limited to the following:
(1) Alternative monitoring requirements when installation of a
continuous monitoring system or monitoring device specified by this part
would not provide accurate measurements due to liquid water or other
interferences caused by substances in the effluent gases.
(2) Alternative monitoring requirements when the affected facility
is infrequently operated.
(3) Alternative monitoring requirements to accommodate continuous
monitoring systems that require additional measurements to correct for
stack moisture conditions.
(4) Alternative locations for installing continuous monitoring
systems or monitoring devices when the owner or operator can demonstrate
that installation at alternate locations will enable accurate and
representative measurements.
(5) Alternative methods of converting pollutant concentration
measurements to units of the standards.
(6) Alternative procedures for performing daily checks of zero and
span drift that do not involve use of span gases or test cells.
(7) Alternatives to the A.S.T.M. test methods or sampling procedures
specified by any subpart.
(8) Alternative continuous monitoring systems that do not meet the
design or performance requirements in Performance Specification 1,
appendix B, but adequately demonstrate a definite and consistent
relationship between its measurements and the measurements of opacity by
a system complying with the requirements in Performance Specification 1.
The Administrator may require that such demonstration be performed for
each affected facility.
(9) Alternative monitoring requirements when the effluent from a
single affected facility or the combined effluent from two or more
affected facilities is released to the atmosphere through more than one
point.
(j) An alternative to the relative accuracy (RA) test specified in
Performance Specification 2 of appendix B may be requested as follows:
(1) An alternative to the reference method tests for determining RA
is available for sources with emission rates demonstrated to be less
than 50 percent of the applicable standard. A source owner or operator
may petition the Administrator to waive the RA test in Section 8.4 of
Performance Specification 2 and substitute the procedures in Section
16.0 if the results of a performance test conducted according to the
requirements in Sec. 60.8 of this subpart or other tests performed
following the criteria in Sec. 60.8 demonstrate that the emission rate
of the pollutant of interest in the units of the applicable standard is
less than 50 percent of the applicable standard. For sources subject to
standards expressed as control efficiency levels, a source owner or
operator may petition the Administrator to waive the RA test and
substitute the procedures in Section 16.0 of Performance Specification 2
if the control device exhaust emission rate is less than 50 percent of
the level needed to meet the control efficiency requirement. The
alternative procedures do not apply if the continuous emission
monitoring system is used to determine compliance continuously with the
applicable standard. The petition to waive the RA test shall include a
detailed description of the procedures to be applied. Included shall be
location and procedure for conducting the alternative, the concentration
or response levels of the alternative RA materials, and the other
equipment checks included in the alternative procedure. The
Administrator will review the petition for completeness and
applicability. The determination to grant a waiver will depend on the
intended use of the CEMS data (e.g., data collection purposes other than
NSPS) and may require specifications more stringent than in Performance
Specification 2 (e.g., the applicable emission limit is more stringent
than NSPS).
(2) The waiver of a CEMS RA test will be reviewed and may be
rescinded at such time, following successful completion of the
alternative RA procedure, that the CEMS data indicate that the source
emissions are approaching the level. The criterion for reviewing
[[Page 56]]
the waiver is the collection of CEMS data showing that emissions have
exceeded 70 percent of the applicable standard for seven, consecutive,
averaging periods as specified by the applicable regulation(s). For
sources subject to standards expressed as control efficiency levels, the
criterion for reviewing the waiver is the collection of CEMS data
showing that exhaust emissions have exceeded 70 percent of the level
needed to meet the control efficiency requirement for seven,
consecutive, averaging periods as specified by the applicable
regulation(s) [e.g., Sec. 60.45(g) (2) and (3), Sec. 60.73(e), and
Sec. 60.84(e)]. It is the responsibility of the source operator to
maintain records and determine the level of emissions relative to the
criterion on the waiver of RA testing. If this criterion is exceeded,
the owner or operator must notify the Administrator within 10 days of
such occurrence and include a description of the nature and cause of the
increasing emissions. The Administrator will review the notification and
may rescind the waiver and require the owner or operator to conduct a RA
test of the CEMS as specified in Section 8.4 of Performance
Specification 2.
[40 FR 46255, Oct. 6, 1975; 40 FR 59205, Dec. 22, 1975, as amended at 41
FR 35185, Aug. 20, 1976; 48 FR 13326, Mar. 30, 1983; 48 FR 23610, May
25, 1983; 48 FR 32986, July 20, 1983; 52 FR 9782, Mar. 26, 1987; 52 FR
17555, May 11, 1987; 52 FR 21007, June 4, 1987; 64 FR 7463, Feb. 12,
1999; 65 FR 48920, Aug. 10, 2000; 65 FR 61749, Oct. 17, 2000]
Editorial Note: At 65 FR 61749, Oct. 17, 2000, Sec. 60.13 was
amended by revising the words ``ng/J of pollutant'' to read ``ng of
pollutant per J of heat input'' in the sixth sentence of paragraph (h).
However, the amendment could not be incorporated because the words ``ng/
J of pollutant'' do not exist in the sixth sentence of paragraph (h).
Sec. 60.14 Modification.
(a) Except as provided under paragraphs (e) and (f) of this section,
any physical or operational change to an existing facility which results
in an increase in the emission rate to the atmosphere of any pollutant
to which a standard applies shall be considered a modification within
the meaning of section 111 of the Act. Upon modification, an existing
facility shall become an affected facility for each pollutant to which a
standard applies and for which there is an increase in the emission rate
to the atmosphere.
(b) Emission rate shall be expressed as kg/hr of any pollutant
discharged into the atmosphere for which a standard is applicable. The
Administrator shall use the following to determine emission rate:
(1) Emission factors as specified in the latest issue of
``Compilation of Air Pollutant Emission Factors,'' EPA Publication No.
AP-42, or other emission factors determined by the Administrator to be
superior to AP-42 emission factors, in cases where utilization of
emission factors demonstrates that the emission level resulting from the
physical or operational change will either clearly increase or clearly
not increase.
(2) Material balances, continuous monitor data, or manual emission
tests in cases where utilization of emission factors as referenced in
paragraph (b)(1) of this section does not demonstrate to the
Administrator's satisfaction whether the emission level resulting from
the physical or operational change will either clearly increase or
clearly not increase, or where an owner or operator demonstrates to the
Administrator's satisfaction that there are reasonable grounds to
dispute the result obtained by the Administrator utilizing emission
factors as referenced in paragraph (b)(1) of this section. When the
emission rate is based on results from manual emission tests or
continuous monitoring systems, the procedures specified in appendix C of
this part shall be used to determine whether an increase in emission
rate has occurred. Tests shall be conducted under such conditions as the
Administrator shall specify to the owner or operator based on
representative performance of the facility. At least three valid test
runs must be conducted before and at least three after the physical or
operational change. All operating parameters which may affect emissions
must be held constant to the maximum feasible degree for all test runs.
(c) The addition of an affected facility to a stationary source as
an expansion to that source or as a replacement for an existing facility
shall not by
[[Page 57]]
itself bring within the applicability of this part any other facility
within that source.
(d) [Reserved]
(e) The following shall not, by themselves, be considered
modifications under this part:
(1) Maintenance, repair, and replacement which the Administrator
determines to be routine for a source category, subject to the
provisions of paragraph (c) of this section and Sec. 60.15.
(2) An increase in production rate of an existing facility, if that
increase can be accomplished without a capital expenditure on that
facility.
(3) An increase in the hours of operation.
(4) Use of an alternative fuel or raw material if, prior to the date
any standard under this part becomes applicable to that source type, as
provided by Sec. 60.1, the existing facility was designed to accommodate
that alternative use. A facility shall be considered to be designed to
accommodate an alternative fuel or raw material if that use could be
accomplished under the facility's construction specifications as amended
prior to the change. Conversion to coal required for energy
considerations, as specified in section 111(a)(8) of the Act, shall not
be considered a modification.
(5) The addition or use of any system or device whose primary
function is the reduction of air pollutants, except when an emission
control system is removed or is replaced by a system which the
Administrator determines to be less environmentally beneficial.
(6) The relocation or change in ownership of an existing facility.
(f) Special provisions set forth under an applicable subpart of this
part shall supersede any conflicting provisions of this section.
(g) Within 180 days of the completion of any physical or operational
change subject to the control measures specified in paragraph (a) of
this section, compliance with all applicable standards must be achieved.
(h) No physical change, or change in the method of operation, at an
existing electric utility steam generating unit shall be treated as a
modification for the purposes of this section provided that such change
does not increase the maximum hourly emissions of any pollutant
regulated under this section above the maximum hourly emissions
achievable at that unit during the 5 years prior to the change.
(i) Repowering projects that are awarded funding from the Department
of Energy as permanent clean coal technology demonstration projects (or
similar projects funded by EPA) are exempt from the requirements of this
section provided that such change does not increase the maximum hourly
emissions of any pollutant regulated under this section above the
maximum hourly emissions achievable at that unit during the five years
prior to the change.
(j)(1) Repowering projects that qualify for an extension under
section 409(b) of the Clean Air Act are exempt from the requirements of
this section, provided that such change does not increase the actual
hourly emissions of any pollutant regulated under this section above the
actual hourly emissions achievable at that unit during the 5 years prior
to the change.
(2) This exemption shall not apply to any new unit that:
(i) Is designated as a replacement for an existing unit;
(ii) Qualifies under section 409(b) of the Clean Air Act for an
extension of an emission limitation compliance date under section 405 of
the Clean Air Act; and
(iii) Is located at a different site than the existing unit.
(k) The installation, operation, cessation, or removal of a
temporary clean coal technology demonstration project is exempt from the
requirements of this section. A temporary clean coal control technology
demonstration project, for the purposes of this section is a clean coal
technology demonstration project that is operated for a period of 5
years or less, and which complies with the State implementation plan for
the State in which the project is located and other requirements
necessary to attain and maintain the national ambient air quality
standards during the project and after it is terminated.
[[Page 58]]
(l) The reactivation of a very clean coal-fired electric utility
steam generating unit is exempt from the requirements of this section.
[40 FR 58419, Dec. 16, 1975, as amended at 43 FR 34347, Aug. 3, 1978; 45
FR 5617, Jan. 23, 1980; 57 FR 32339, July 21, 1992; 65 FR 61750, Oct.
17, 2000]
Sec. 60.15 Reconstruction.
(a) An existing facility, upon reconstruction, becomes an affected
facility, irrespective of any change in emission rate.
(b) ``Reconstruction'' means the replacement of components of an
existing facility to such an extent that:
(1) The fixed capital cost of the new components exceeds 50 percent
of the fixed capital cost that would be required to construct a
comparable entirely new facility, and
(2) It is technologically and economically feasible to meet the
applicable standards set forth in this part.
(c) ``Fixed capital cost'' means the capital needed to provide all
the depreciable components.
(d) If an owner or operator of an existing facility proposes to
replace components, and the fixed capital cost of the new components
exceeds 50 percent of the fixed capital cost that would be required to
construct a comparable entirely new facility, he shall notify the
Administrator of the proposed replacements. The notice must be
postmarked 60 days (or as soon as practicable) before construction of
the replacements is commenced and must include the following
information:
(1) Name and address of the owner or operator.
(2) The location of the existing facility.
(3) A brief description of the existing facility and the components
which are to be replaced.
(4) A description of the existing air pollution control equipment
and the proposed air pollution control equipment.
(5) An estimate of the fixed capital cost of the replacements and of
constructing a comparable entirely new facility.
(6) The estimated life of the existing facility after the
replacements.
(7) A discussion of any economic or technical limitations the
facility may have in complying with the applicable standards of
performance after the proposed replacements.
(e) The Administrator will determine, within 30 days of the receipt
of the notice required by paragraph (d) of this section and any
additional information he may reasonably require, whether the proposed
replacement constitutes reconstruction.
(f) The Administrator's determination under paragraph (e) shall be
based on:
(1) The fixed capital cost of the replacements in comparison to the
fixed capital cost that would be required to construct a comparable
entirely new facility;
(2) The estimated life of the facility after the replacements
compared to the life of a comparable entirely new facility;
(3) The extent to which the components being replaced cause or
contribute to the emissions from the facility; and
(4) Any economic or technical limitations on compliance with
applicable standards of performance which are inherent in the proposed
replacements.
(g) Individual subparts of this part may include specific provisions
which refine and delimit the concept of reconstruction set forth in this
section.
[40 FR 58420, Dec. 16, 1975]
Sec. 60.16 Priority list.
Prioritized Major Source Categories
------------------------------------------------------------------------
Priority Number \1\ Source Category
------------------------------------------------------------------------
1. Synthetic Organic Chemical Manufacturing
Industry (SOCMI) and Volatile Organic
Liquid Storage Vessels and Handling
Equipment
(a) SOCMI unit processes
(b) Volatile organic liquid (VOL)
storage vessels and handling equipment
(c) SOCMI fugitive sources
(d) SOCMI secondary sources
2. Industrial Surface Coating: Cans
3. Petroleum Refineries: Fugitive Sources
4. Industrial Surface Coating: Paper
5. Dry Cleaning
(a) Perchloroethylene
(b) Petroleum solvent
6. Graphic Arts
7. Polymers and Resins: Acrylic Resins
8. Mineral Wool (Deleted)
9. Stationary Internal Combustion Engines
[[Page 59]]
10. Industrial Surface Coating: Fabric
11. Industrial-Commercial-Institutional
Steam Generating Units.
12. Incineration: Non-Municipal (Deleted)
13. Non-Metallic Mineral Processing
14. Metallic Mineral Processing
15. Secondary Copper (Deleted)
16. Phosphate Rock Preparation
17. Foundries: Steel and Gray Iron
18. Polymers and Resins: Polyethylene
19. Charcoal Production
20. Synthetic Rubber
(a) Tire manufacture
(b) SBR production
21. Vegetable Oil
22. Industrial Surface Coating: Metal Coil
23. Petroleum Transportation and Marketing
24. By-Product Coke Ovens
25. Synthetic Fibers
26. Plywood Manufacture
27. Industrial Surface Coating: Automobiles
28. Industrial Surface Coating: Large
Appliances
29. Crude Oil and Natural Gas Production
30. Secondary Aluminum
31. Potash (Deleted)
32. Lightweight Aggregate Industry: Clay,
Shale, and Slate \2\
33. Glass
34. Gypsum
35. Sodium Carbonate
36. Secondary Zinc (Deleted)
37. Polymers and Resins: Phenolic
38. Polymers and Resins: Urea-Melamine
39. Ammonia (Deleted)
40. Polymers and Resins: Polystyrene
41. Polymers and Resins: ABS-SAN Resins
42. Fiberglass
43. Polymers and Resins: Polypropylene
44. Textile Processing
45. Asphalt Processing and Asphalt Roofing
Manufacture
46. Brick and Related Clay Products
47. Ceramic Clay Manufacturing (Deleted)
48. Ammonium Nitrate Fertilizer
49. Castable Refractories (Deleted)
50. Borax and Boric Acid (Deleted)
51. Polymers and Resins: Polyester Resins
52. Ammonium Sulfate
53. Starch
54. Perlite
55. Phosphoric Acid: Thermal Process
(Deleted)
56. Uranium Refining
57. Animal Feed Defluorination (Deleted)
58. Urea (for fertilizer and polymers)
59. Detergent (Deleted)
Other Source Categories
Lead acid battery manufacture \3\
Organic solvent cleaning \3\
Industrial surface coating: metal furniture \3\
Stationary gas turbines \4\
Municipal solid waste landfills \4\
------------------------------------------------------------------------
\1\ Low numbers have highest priority, e.g., No. 1 is high priority, No.
59 is low priority.
\2\ Formerly titled ``Sintering: Clay and Fly Ash''.
\3\ Minor source category, but included on list since an NSPS is being
developed for that source category.
\4\ Not prioritized, since an NSPS for this major source category has
already been promulgated.
[47 FR 951, Jan. 8, 1982, as amended at 47 FR 31876, July 23, 1982; 51
FR 42796, Nov. 25, 1986; 52 FR 11428, Apr. 8, 1987; 61 FR 9919, Mar. 12,
1996]
Sec. 60.17 Incorporations by reference.
The materials listed below are incorporated by reference in the
corresponding sections noted. These incorporations by reference were
approved by the Director of the Federal Register on the date listed.
These materials are incorporated as they exist on the date of the
approval, and a notice of any change in these materials will be
published in the Federal Register. The materials are available for
purchase at the corresponding address noted below, and all are available
for inspection at the Office of the Federal Register, 800 North Capitol
Street, NW., suite 700, Washington, DC and at the Library (MD-35), U.S.
EPA, Research Triangle Park, NC.
(a) The following materials are available for purchase from at least
one of the following addresses: American Society for Testing and
Materials (ASTM), 1916 Race Street, Philadelphia, PA 19103; or
University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI
48106.
(1) ASTM A99-76, 82 (Reapproved 1987), Standard Specification for
Ferromanganese, incorporation by reference (IBR) approved January 27,
1983 for Sec. 60.261.
(2) ASTM A100-69, 74, 93, Standard Specification for Ferrosilicon,
IBR approved January 27, 1983 for Sec. 60.261.
(3) ASTM A101-73, 93, Standard Specification for Ferrochromium, IBR
approved January 27, 1983 for Sec. 60.261.
(4) ASTM A482-76, 93, Standard Specification for Ferrochromesilicon,
IBR approved January 27, 1983 for Sec. 60.261.
(5) ASTM A483-64, 74 (Reapproved 1988), Standard Specification for
Silicomanganese, IBR approved January 27, 1983 for Sec. 60.261.
(6) ASTM A495-76, 94, Standard Specification for Calcium-Silicon and
Calcium Manganese-Silicon, IBR approved January 27, 1983 for
Sec. 60.261.
(7) ASTM D86-78, 82, 90, 93, 95, 96, Distillation of Petroleum
Products, IBR approved for Secs. 60.562-2(d), 60.593(d), and 60.633(h).
(8) ASTM D129-64, 78, 95, Standard Test Method for Sulfur in
Petroleum Products (General Bomb Method), IBR approved for Appendix A:
Method 19, Section 12.5.2.2.3; and Sec. 60.106(j)(2).
[[Page 60]]
(9) ASTM D240-76, 92, Standard Test Method for Heat of Combustion of
Liquid Hydrocarbon Fuels by Bomb Calorimeter, IBR approved January 27,
1983 for Secs. 60.46(c), 60.296(b), and Appendix A: Method 19, Section
12.5.2.2.3.
(10) ASTM D270-65, 75, Standard Method of Sampling Petroleum and
Petroleum Products, IBR approved January 27, 1983 for Appendix A: Method
19, Section 12.5.2.2.1.
(11) ASTM D323-82, 94, Test Method for Vapor Pressure of Petroleum
Products (Reid Method), IBR approved April 8, 1987 for Secs. 60.111(l),
60.111a(g), 60.111b(g), and 60.116b(f)(2)(ii).
(12) ASTM D388-77, 90, 91, 95, 98a, Standard Specification for
Classification of Coals by Rank, IBR approved for Secs. 60.41(f),
60.45(f)(4)(i), 60.45(f)(4)(ii), 60.45(f)(4)(vi), 60.41a, 60.41b, and
60.251(b) and (c).
(13) ASTM D396-78, 89, 90, 92, 96, 98, Standard Specification for
Fuel Oils, IBR approved for Secs. 60.41b, 60.41c, 60.111(b), and
60.111a(b).
(14) ASTM D975-78, 96, 98a, Standard Specification for Diesel Fuel
Oils, IBR approved January 27, 1983 for Secs. 60.111(b) and 60.111a(b).
(15) ASTM D1072-80, 90 (Reapproved 1994), Standard Method for Total
Sulfur in Fuel Gases, IBR approved July 31, 1984 for Sec. 60.335(d).
(16) ASTM D1137-53, 75, Standard Method for Analysis of Natural
Gases and Related Types of Gaseous Mixtures by the Mass Spectrometer,
IBR approved January 27, 1983 for Sec. 60.45(f)(5)(i).
(17) ASTM D1193-77, 91, Standard Specification for Reagent Water,
IBR approved for Appendix A: Method 5, Section 7.1.3; Method 5E, Section
7.2.1; Method 5F, Section 7.2.1; Method 6, Section 7.1.1; Method 7,
Section 7.1.1; Method 7C, Section 7.1.1; Method 7D, Section 7.1.1;
Method 10A, Section 7.1.1; Method 11, Section 7.1.3; Method 12, Section
7.1.3; Method 13A, Section 7.1.2; Method 26, Section 7.1.2; Method 26A,
Section 7.1.2; and Method 29, Section 7.2.2.
(18) ASTM D1266-87, 91, 98, Standard Test Method for Sulfur in
Petroleum Products (Lamp Method), IBR approved August 17, 1989 for
Sec. 60.106(j)(2).
(19) ASTM D1475-60 (Reapproved 1980), 90, Standard Test Method for
Density of Paint, Varnish Lacquer, and Related Products, IBR approved
January 27, 1983 for Sec. 60.435(d)(1), Appendix A: Method 24, Section
6.1; and Method 24A, Sections 6.5 and 7.1.
(20) ASTM D1552-83, 95, Standard Test Method for Sulfur in Petroleum
Products (High Temperature Method), IBR approved for Appendix A: Method
19, Section 12.5.2.2.3; and Sec. 60.106(j)(2).
(21) ASTM D1826-77, 94, Standard Test Method for Calorific Value of
Gases in Natural Gas Range by Continuous Recording Calorimeter, IBR
approved January 27, 1983 for Secs. 60.45(f)(5)(ii), 60.46(c)(2),
60.296(b)(3), and Appendix A: Method 19, Section 12.3.2.4.
(22) ASTM D1835-87, 91, 97, Standard Specification for Liquefied
Petroleum (LP) Gases, approved for Secs. 60.41b and 60.41c.
(23) ASTM D1945-64, 76, 91, 96, Standard Method for Analysis of
Natural Gas by Gas Chromatography, IBR approved January 27, 1983 for
Sec. 60.45(f)(5)(i).
(24) ASTM D1946-77, 90 (Reapproved 1994), Standard Method for
Analysis of Reformed Gas by Gas Chromatography, IBR approved for
Secs. 60.45(f)(5)(i), 60.18(f)(3), 60.614(e)(2)(ii), 60.614(e)(4),
60.664(e)(2)(ii), 60.664(e)(4), 60.564(f)(1), 60.704(d)(2)(ii), and
60.704(d)(4).
(25) ASTM D2013-72, 86, Standard Method of Preparing Coal Samples
for Analysis, IBR approved January 27, 1983, for Appendix A: Method 19,
Section 12.5.2.1.3.
(26) ASTM D2015-77 (Reapproved 1978), 96, Standard Test Method for
Gross Calorific Value of Solid Fuel by the Adiabatic Bomb Calorimeter,
IBR approved January 27, 1983 for Sec. 60.45(f)(5)(ii), 60.46(c)(2), and
Appendix A: Method 19, Section 12.5.2.1.3.
(27) ASTM D2016-74, 83, Standard Test Methods for Moisture Content
of Wood, IBR approved for Appendix A: Method 28, Section 16.1.1.
(28) ASTM D2234-76, 96, 97b, 98, Standard Methods for Collection of
a Gross Sample of Coal, IBR approved January 27, 1983 for Appendix A:
Method 19, Section 12.5.2.1.1.
(29) ASTM D2369-81, 87, 90, 92, 93, 95, Standard Test Method for
Volatile Content of Coatings, IBR approved January 27, 1983 for Appendix
A: Method 24, Section 6.2.
(30) ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by
Bomb Calorimeter (High-Precision Method), IBR approved for
Secs. 60.18(f)(3), 60.485(g)(6), 60.614(e)(4), 60.664(e)(4),
60.564(f)(3), and 60.704(d)(4).
(31) ASTM D2504-67, 77, 88 (Reapproved 1993), Noncondensable Gases
in C3 and Lighter Hydrocarbon Products by Gas Chromatography,
IBR approved for Sec. 60.485(g)(5).
(32) ASTM D2584-68 (Reapproved 1985), 94, Standard Test Method for
Ignition Loss of Cured Reinforced Resins, IBR approved February 25, 1985
for Sec. 60.685(c)(3)(i).
(33) ASTM D2622-87, 94, 98, Standard Test Method for Sulfur in
Petroleum Products by X-Ray Spectrometry, IBR approved August 17, 1989
for Sec. 60.106(j)(2).
(34) ASTM D2879-83, 96, 97, Test Method for Vapor Pressure-
Temperature Relationship and Initial Decomposition Temperature of
Liquids by Isoteniscope, IBR approved April 8, 1987 for
Secs. 60.485(e)(1), 60.111b(f)(3), 60.116b(e)(3)(ii), and
60.116b(f)(2)(i).
(35) ASTM D2880-78, 96, Standard Specification for Gas Turbine Fuel
Oils, IBR approved January 27, 1983 for Secs. 60.111(b), 60.111a(b), and
60.335(d).
(36) ASTM D2908-74, 91, Standard Practice for Measuring Volatile
Organic Matter in Water by Aqueous-Injection Gas Chromatography, IBR
approved for Sec. 60.564(j).
[[Page 61]]
(37) ASTM D2986-71, 78, 95a, Standard Method for Evaluation of Air,
Assay Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke Test, IBR
approved January 27, 1983 for Appendix A: Method 5, Section 7.1.1;
Method 12, Section 7.1.1; and Method 13A, Section 7.1.1.2.
(38) ASTM D3031-81, Standard Test Method for Total Sulfur in Natural
Gas by Hydrogenation, IBR approved July 31, 1984 for Sec. 60.335(d).
(39) ASTM D3173-73, 87, Standard Test Method for Moisture in the
Analysis Sample of Coal and Coke, IBR approved January 27, 1983 for
Appendix A: Method 19, Section 12.5.2.1.3.
(40) ASTM D3176-74, 89, Standard Method for Ultimate Analysis of
Coal and Coke, IBR approved January 27, 1983 for Sec. 60.45(f)(5)(i) and
Appendix A: Method 19, Section 12.3.2.3.
(41) ASTM D3177-75, 89, Standard Test Method for Total Sulfur in the
Analysis Sample of Coal and Coke, IBR approved January 27, 1983 for
Appendix A: Method 19, Section 12.5.2.1.3.
(42) ASTM D3178-73 (Reapproved 1979), 89, Standard Test Methods for
Carbon and Hydrogen in the Analysis Sample of Coal and Coke, IBR
approved January 27, 1983 for Sec. 60.45(f)(5)(i).
(43) ASTM D3246-81, 92, 96, Standard Method for Sulfur in Petroleum
Gas by Oxidative Microcoulometry, IBR approved July 31, 1984 for
Sec. 60.335(d).
(44) ASTM D3270-73T, 80, 91, 95, Standard Test Methods for Analysis
for Fluoride Content of the Atmosphere and Plant Tissues (Semiautomated
Method), IBR approved for Appendix A: Method 13A, Section 16.1.
(45) ASTM D3286-85, 96, Standard Test Method for Gross Calorific
Value of Coal and Coke by the Isoperibol Bomb Calorimeter, IBR approved
for Appendix A: Method 19, Section 12.5.2.1.3.
(46) ASTM D3370-76, 95a, Standard Practices for Sampling Water, IBR
approved for Sec. 60.564(j).
(47) ASTM D3792-79, 91, Standard Test Method for Water Content of
Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR
approved January 27, 1983 for Appendix A: Method 24, Section 6.3.
(48) ASTM D4017-81, 90, 96a, Standard Test Method for Water in
Paints and Paint Materials by the Karl Fischer Titration Method, IBR
approved January 27, 1983 for Appendix A: Method 24, Section 6.4.
(49) ASTM D4057-81, 95, Standard Practice for Manual Sampling of
Petroleum and Petroleum Products, IBR approved for Appendix A: Method
19, Section 12.5.2.2.3.
(50) ASTM D4084-82, 94, Standard Method for Analysis of Hydrogen
Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR
approved July 31, 1984 for Sec. 60.335(d).
(51) ASTM D4177-95, Standard Practice for Automatic Sampling of
Petroleum and Petroleum Products, IBR approved for Appendix A: Method
19, 12.5.2.2.1.
(52) ASTM D4239-85, 94, 97, Standard Test Methods for Sulfur in the
Analysis Sample of Coal and Coke Using High Temperature Tube Furnace
Combustion Methods, IBR approved for Appendix A: Method 19, Section
12.5.2.1.3.
(53) ASTM D4442-84, 92, Standard Test Methods for Direct Moisture
Content Measurement in Wood and Wood-base Materials, IBR approved for
Appendix A: Method 28, Section 16.1.1.
(54) ASTM D4444-92, Standard Test Methods for Use and Calibration of
Hand-Held Moisture Meters, IBR approved for Appendix A: Method 28,
Section 16.1.1.
(55) ASTM D4457-85 (Reapproved 1991), Test Method for Determination
of Dichloromethane and 1, 1, 1-Trichloroethane in Paints and Coatings by
Direct Injection into a Gas Chromatograph, IBR approved for Appendix A:
Method 24, Section 6.5.
(56) ASTM D4809-95, Standard Test Method for Heat of Combustion of
Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR
approved for Secs. 60.18(f)(3), 60.485(g)(6), 60.564(f)(3),
60.614(d)(4), 60.664(e)(4), and 60.704(d)(4).
(57) ASTM D5403-93, Standard Test Methods for Volatile Content of
Radiation Curable Materials. IBR approved September 11, 1995 for
Appendix A: Method 24, Section 6.6.
(58) ASTM D5865-98, Standard Test Method for Gross Calorific Value
of Coal and Coke. IBR approved for Sec. 60.45(f)(5)(ii), 60.46(c)(2),
and Appendix A: Method 19, Section 12.5.2.1.3.
(59) ASTM E168-67, 77, 92, General Techniques of Infrared
Quantitative Analysis, IBR approved for Secs. 60.593(b)(2) and
60.632(f).
(60) ASTM E169-63, 77, 93, General Techniques of Ultraviolet
Quantitative Analysis, IBR approved for Secs. 60.593(b)(2) and
60.632(f).
(61) ASTM E260-73, 91, 96, General Gas Chromatography Procedures,
IBR approved for Secs. 60.593(b)(2) and 60.632(f).
(62)-(63) [Reserved]
(64) ASTM D 6216-98 Standard Practice for Opacity Monitor
Manufacturers to Certify Conformance with Design and Performance
Specifications, IBR approved February 6, 2001 for appendix B, PS-1.
(b) The following material is available for purchase from the
Association of Official Analytical Chemists, 1111 North 19th Street,
Suite 210, Arlington, VA 22209.
(1) AOAC Method 9, Official Methods of Analysis of the Association
of Official Analytical Chemists, 11th edition, 1970, pp. 11-12, IBR
approved January 27, 1983 for Secs. 60.204(b)(3), 60.214(b)(3),
60.224(b)(3), 60.234(b)(3).
(c) The following material is available for purchase from the
American
[[Page 62]]
Petroleum Institute, 1220 L Street NW., Washington, DC 20005.
(1) API Publication 2517, Evaporation Loss from External Floating
Roof Tanks, Second Edition, February 1980, IBR approved January 27,
1983, for Secs. 60.111(i), 60.111a(f), 60.111a(f)(1) and
60.116b(e)(2)(i).
(d) The following material is available for purchase from the
Technical Association of the Pulp and Paper Industry (TAPPI), Dunwoody
Park, Atlanta, GA 30341.
(1) TAPPI Method T624 os-68, IBR approved January 27, 1983 for
Sec. 60.285(d)(3).
(e) The following material is available for purchase from the Water
Pollution Control Federation (WPCF), 2626 Pennsylvania Avenue NW.,
Washington, DC 20037.
(1) Method 209A, Total Residue Dried at 103-105 deg. C, in Standard
Methods for the Examination of Water and Wastewater, 15th Edition, 1980,
IBR approved February 25, 1985 for Sec. 60.683(b).
(f) The following material is available for purchase from the
following address: Underwriter's Laboratories, Inc. (UL), 333 Pfingsten
Road, Northbrook, IL 60062.
(1) UL 103, Sixth Edition revised as of September 3, 1986, Standard
for Chimneys, Factory-built, Residential Type and Building Heating
Appliance.
(g) The following material is available for purchase from the
following address: West Coast Lumber Inspection Bureau, 6980 SW. Barnes
Road, Portland, OR 97223.
(1) West Coast Lumber Standard Grading Rules No. 16, pages 5-21 and
90 and 91, September 3, 1970, revised 1984.
(h) The following material is available for purchase from the
American Society of Mechanical Engineers (ASME), 345 East 47th Street,
New York, NY 10017.
(1) ASME QRO-1-1994, Standard for the Qualification and
Certification of Resource Recovery Facility Operators, IBR approved for
Secs. 60.56a, 60.54b(a), 60.54b(b), 60.1185(a), 60.1185(c)(2),
60.1675(a), and 60.1675(c)(2).
(2) ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test Codes: Test Code
for Steam Generating Units (with 1968 and 1969 Addenda), IBR approved
for Secs. 60.46b, 60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)(3) and
60.1810(a)(3).
(3) ASME Interim Supplement 19.5 on Instruments and Apparatus:
Application, Part II of Fluid Meters, 6th Edition (1971), IBR approved
for Secs. 60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)4), and
60.1810(a)(4).
(i) Test Methods for Evaluating Solid Waste, Physical/Chemical
Methods,'' EPA Publication SW-846 Third Edition (November 1986), as
amended by Updates I (July 1992), II (September 1994), IIA (August,
1993), IIB (January 1995), and III (December 1996). This document may be
obtained from the U.S. EPA, Office of Solid Waste and Emergency
Response, Waste Characterization Branch, Washington, DC 20460, and is
incorporated by reference for appendix A to part 60, Method 29, Sections
7.5.34; 9.2.1; 9.2.3; 10.2; 10.3; 11.1.1; 11.1.3; 13.2.1; 13.2.2;
13.3.1; and Table 29-3.
(j) ``Standard Methods for the Examination of Water and
Wastewater,'' 16th edition, 1985. Method 303F: ``Determination of
Mercury by the Cold Vapor Technique.'' This document may be obtained
from the American Public Health Association, 1015 18th Street, NW.,
Washington, DC 20036, and is incorporated by reference for appendix A to
part 60, Method 29, Sections 9.2.3; 10.3; and 11.1.3.
(k) This material is available for purchase from the American
Hospital Association (AHA) Service, Inc., Post Office Box 92683,
Chicago, Illinois 60675-2683. You may inspect a copy at EPA's Air and
Radiation Docket and Information Center (Docket A-91-61, Item IV-J-124),
Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC.
(1) An Ounce of Prevention: Waste Reduction Strategies for Health
Care Facilities. American Society for Health Care Environmental Services
of the American Hospital Association. Chicago, Illinois. 1993. AHA
Catalog No. 057007. ISBN 0-87258-673-5. IBR approved for Sec. 60.35e and
Sec. 60.55c.
(l) This material is available for purchase from the National
Technical Information Services, 5285 Port Royal Road, Springfield,
Virginia 22161. You may inspect a copy at EPA's Air and Radiation Docket
and Information Center (Docket A-91-61, Item IV-J-125), Room M-1500,
1200 Pennsylvania Ave., NW., Washington, DC.
(1) OMB Bulletin No. 93-17: Revised Statistical Definitions for
Metropolitan Areas. Office of Management and Budget, June 30,
[[Page 63]]
1993. NTIS No. PB 93-192-664. IBR approved for Sec. 60.31e.
[48 FR 3735, Jan. 27, 1983]
Editorial Note: For Federal Register citations affecting Sec. 60.17,
see the List of CFR Sections Affected, which appears in the Finding Aids
section of the printed volume and on GPO Access.
Sec. 60.18 General control device requirements.
(a) Introduction. This section contains requirements for control
devices used to comply with applicable subparts of parts 60 and 61. The
requirements are placed here for administrative convenience and only
apply to facilities covered by subparts referring to this section.
(b) Flares. Paragraphs (c) through (f) apply to flares.
(c)(1) Flares shall be designed for and operated with no visible
emissions as determined by the methods specified in paragraph (f),
except for periods not to exceed a total of 5 minutes during any 2
consecutive hours.
(2) Flares shall be operated with a flame present at all times, as
determined by the methods specified in paragraph (f).
(3) An owner/operator has the choice of adhering to either the heat
content specifications in paragraph (c)(3)(ii) of this section and the
maximum tip velocity specifications in paragraph (c)(4) of this section,
or adhering to the requirements in paragraph (c)(3)(i) of this section.
(i)(A) Flares shall be used that have a diameter of 3 inches or
greater, are nonassisted, have a hydrogen content of 8.0 percent (by
volume), or greater, and are designed for and operated with an exit
velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity,
Vmax, as determined by the following equation:
Vmax=(XH2-K1)* K2
Where:
Vmax=Maximum permitted velocity, m/sec.
K1=Constant, 6.0 volume-percent hydrogen.
K2=Constant, 3.9(m/sec)/volume-percent hydrogen.
XH2=The volume-percent of hydrogen, on a wet basis, as
calculated by using the American Society for Testing and Materials
(ASTM) Method D1946-77. (Incorporated by reference as specified in
Sec. 60.17).
(B) The actual exit velocity of a flare shall be determined by the
method specified in paragraph (f)(4) of this section.
(ii) Flares shall be used only with the net heating value of the gas
being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare
is steam-assisted or air-assisted; or with the net heating value of the
gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the
flare is nonassisted. The net heating value of the gas being combusted
shall be determined by the methods specified in paragraph (f)(3) of this
section.
(4)(i) Steam-assisted and nonassisted flares shall be designed for
and operated with an exit velocity, as determined by the methods
specified in paragraph (f)(4) of this section, less than 18.3 m/sec (60
ft/sec), except as provided in paragraphs (c)(4) (ii) and (iii) of this
section.
(ii) Steam-assisted and nonassisted flares designed for and operated
with an exit velocity, as determined by the methods specified in
paragraph (f)(4), equal to or greater than 18.3 m/sec (60 ft/sec) but
less than 122 m/sec (400 ft/sec) are allowed if the net heating value of
the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf).
(iii) Steam-assisted and nonassisted flares designed for and
operated with an exit velocity, as determined by the methods specified
in paragraph (f)(4), less than the velocity, Vmax, as
determined by the method specified in paragraph (f)(5), and less than
122 m/sec (400 ft/sec) are allowed.
(5) Air-assisted flares shall be designed and operated with an exit
velocity less than the velocity, Vmax, as determined by the
method specified in paragraph (f)(6).
(6) Flares used to comply with this section shall be steam-assisted,
air-assisted, or nonassisted.
(d) Owners or operators of flares used to comply with the provisions
of this subpart shall monitor these control devices to ensure that they
are operated and maintained in conformance with their designs.
Applicable subparts will
[[Page 64]]
provide provisions stating how owners or operators of flares shall
monitor these control devices.
(e) Flares used to comply with provisions of this subpart shall be
operated at all times when emissions may be vented to them.
(f)(1) Method 22 of appendix A to this part shall be used to
determine the compliance of flares with the visible emission provisions
of this subpart. The observation period is 2 hours and shall be used
according to Method 22.
(2) The presence of a flare pilot flame shall be monitored using a
thermocouple or any other equivalent device to detect the presence of a
flame.
(3) The net heating value of the gas being combusted in a flare
shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.008
where:
HT=Net heating value of the sample, MJ/scm; where the net
enthalpy per mole of offgas is based on combustion at 25
deg.C and 760 mm Hg, but the standard temperature for
determining the volume corresponding to one mole is 20 deg.C;
[GRAPHIC] [TIFF OMITTED] TC01JN92.009
Ci=Concentration of sample component i in ppm on a wet basis,
as measured for organics by Reference Method 18 and measured
for hydrogen and carbon monoxide by ASTM D1946-77 or 90
(Reapproved 1994) (Incorporated by reference as specified in
Sec. 60.17); and
Hi=Net heat of combustion of sample component i, kcal/g mole
at 25 deg.C and 760 mm Hg. The heats of combustion may be
determined using ASTM D2382-76 or 88 or D4809-95 (incorporated
by reference as specified in Sec. 60.17) if published values
are not available or cannot be calculated.
(4) The actual exit velocity of a flare shall be determined by
dividing the volumetric flowrate (in units of standard temperature and
pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as
appropriate; by the unobstructed (free) cross sectional area of the
flare tip.
(5) The maximum permitted velocity, Vmax, for flares
complying with paragraph (c)(4)(iii) shall be determined by the
following equation.
Log10 (Vmax)=(HT+28.8)/31.7
Vmax=Maximum permitted velocity, M/sec
28.8=Constant
31.7=Constant
HT=The net heating value as determined in paragraph (f)(3).
(6) The maximum permitted velocity, Vmax, for air-
assisted flares shall be determined by the following equation.
Vmax=8.706+0.7084 (HT)
Vmax=Maximum permitted velocity, m/sec
8.706=Constant
0.7084=Constant
HT=The net heating value as determined in paragraph (f)(3).
[51 FR 2701, Jan. 21, 1986, as amended at 63 FR 24444, May 4, 1998; 65
FR 61752, Oct. 17, 2000]
Sec. 60.19 General notification and reporting requirements.
(a) For the purposes of this part, time periods specified in days
shall be measured in calendar days, even if the word ``calendar'' is
absent, unless otherwise specified in an applicable requirement.
(b) For the purposes of this part, if an explicit postmark deadline
is not specified in an applicable requirement for the submittal of a
notification, application, report, or other written communication to the
Administrator, the owner or operator shall postmark the submittal on or
before the number of days specified in the applicable requirement. For
example, if a notification must be submitted 15 days before
[[Page 65]]
a particular event is scheduled to take place, the notification shall be
postmarked on or before 15 days preceding the event; likewise, if a
notification must be submitted 15 days after a particular event takes
place, the notification shall be delivered or postmarked on or before 15
days following the end of the event. The use of reliable non-Government
mail carriers that provide indications of verifiable delivery of
information required to be submitted to the Administrator, similar to
the postmark provided by the U.S. Postal Service, or alternative means
of delivery, including the use of electronic media, agreed to by the
permitting authority, is acceptable.
(c) Notwithstanding time periods or postmark deadlines specified in
this part for the submittal of information to the Administrator by an
owner or operator, or the review of such information by the
Administrator, such time periods or deadlines may be changed by mutual
agreement between the owner or operator and the Administrator.
Procedures governing the implementation of this provision are specified
in paragraph (f) of this section.
(d) If an owner or operator of an affected facility in a State with
delegated authority is required to submit periodic reports under this
part to the State, and if the State has an established timeline for the
submission of periodic reports that is consistent with the reporting
frequency(ies) specified for such facility under this part, the owner or
operator may change the dates by which periodic reports under this part
shall be submitted (without changing the frequency of reporting) to be
consistent with the State's schedule by mutual agreement between the
owner or operator and the State. The allowance in the previous sentence
applies in each State beginning 1 year after the affected facility is
required to be in compliance with the applicable subpart in this part.
Procedures governing the implementation of this provision are specified
in paragraph (f) of this section.
(e) If an owner or operator supervises one or more stationary
sources affected by standards set under this part and standards set
under part 61, part 63, or both such parts of this chapter, he/she may
arrange by mutual agreement between the owner or operator and the
Administrator (or the State with an approved permit program) a common
schedule on which periodic reports required by each applicable standard
shall be submitted throughout the year. The allowance in the previous
sentence applies in each State beginning 1 year after the stationary
source is required to be in compliance with the applicable subpart in
this part, or 1 year after the stationary source is required to be in
compliance with the applicable 40 CFR part 61 or part 63 of this chapter
standard, whichever is latest. Procedures governing the implementation
of this provision are specified in paragraph (f) of this section.
(f)(1)(i) Until an adjustment of a time period or postmark deadline
has been approved by the Administrator under paragraphs (f)(2) and
(f)(3) of this section, the owner or operator of an affected facility
remains strictly subject to the requirements of this part.
(ii) An owner or operator shall request the adjustment provided for
in paragraphs (f)(2) and (f)(3) of this section each time he or she
wishes to change an applicable time period or postmark deadline
specified in this part.
(2) Notwithstanding time periods or postmark deadlines specified in
this part for the submittal of information to the Administrator by an
owner or operator, or the review of such information by the
Administrator, such time periods or deadlines may be changed by mutual
agreement between the owner or operator and the Administrator. An owner
or operator who wishes to request a change in a time period or postmark
deadline for a particular requirement shall request the adjustment in
writing as soon as practicable before the subject activity is required
to take place. The owner or operator shall include in the request
whatever information he or she considers useful to convince the
Administrator that an adjustment is warranted.
(3) If, in the Administrator's judgment, an owner or operator's
request for an adjustment to a particular time period or postmark
deadline is warranted, the Administrator will approve
[[Page 66]]
the adjustment. The Administrator will notify the owner or operator in
writing of approval or disapproval of the request for an adjustment
within 15 calendar days of receiving sufficient information to evaluate
the request.
(4) If the Administrator is unable to meet a specified deadline, he
or she will notify the owner or operator of any significant delay and
inform the owner or operator of the amended schedule.
[59 FR 12428, Mar. 16, 1994, as amended at 64 FR 7463, Feb. 12, 1998]
Subpart B--Adoption and Submittal of State Plans for Designated
Facilities
Source: 40 FR 53346, Nov. 17, 1975, unless otherwise noted.
Sec. 60.20 Applicability.
The provisions of this subpart apply to States upon publication of a
final guideline document under Sec. 60.22(a).
Sec. 60.21 Definitions.
Terms used but not defined in this subpart shall have the meaning
given them in the Act and in subpart A:
(a) Designated pollutant means any air pollutant, emissions of which
are subject to a standard of performance for new stationary sources but
for which air quality criteria have not been issued, and which is not
included on a list published under section 108(a) or section
112(b)(1)(A) of the Act.
(b) Designated facility means any existing facility (see
Sec. 60.2(aa)) which emits a designated pollutant and which would be
subject to a standard of performance for that pollutant if the existing
facility were an affected facility (see Sec. 60.2(e)).
(c) Plan means a plan under section 111(d) of the Act which
establishes emission standards for designated pollutants from designated
facilities and provides for the implementation and enforcement of such
emission standards.
(d) Applicable plan means the plan, or most recent revision thereof,
which has been approved under Sec. 60.27(b) or promulgated under
Sec. 60.27(d).
(e) Emission guideline means a guideline set forth in subpart C of
this part, or in a final guideline document published under
Sec. 60.22(a), which reflects the degree of emission reduction
achievable through the application of the best system of emission
reduction which (taking into account the cost of such reduction) the
Administrator has determined has been adequately demonstrated for
designated facilities.
(f) Emission standard means a legally enforceable regulation setting
forth an allowable rate of emissions into the atmosphere, or prescribing
equipment specifications for control of air pollution emissions.
(g) Compliance schedule means a legally enforceable schedule
specifying a date or dates by which a source or category of sources must
comply with specific emission standards contained in a plan or with any
increments of progress to achieve such compliance.
(h) Increments of progress means steps to achieve compliance which
must be taken by an owner or operator of a designated facility,
including:
(1) Submittal of a final control plan for the designated facility to
the appropriate air pollution control agency;
(2) Awarding of contracts for emission control systems or for
process modifications, or issuance of orders for the purchase of
component parts to accomplish emission control or process modification;
(3) Initiation of on-site construction or installation of emission
control equipment or process change;
(4) Completion of on-site construction or installation of emission
control equipment or process change; and
(5) Final compliance.
(i) Region means an air quality control region designated under
section 107 of the Act and described in part 81 of this chapter.
(j) Local agency means any local governmental agency.
Sec. 60.22 Publication of guideline documents, emission guidelines, and final compliance times.
(a) Concurrently upon or after proposal of standards of performance
for the control of a designated pollutant from affected facilities, the
Administrator will publish a draft guideline
[[Page 67]]
document containing information pertinent to control of the designated
pollutant form designated facilities. Notice of the availability of the
draft guideline document will be published in the Federal Register and
public comments on its contents will be invited. After consideration of
public comments and upon or after promulgation of standards of
performance for control of a designated pollutant from affected
facilities, a final guideline document will be published and notice of
its availability will be published in the Federal Register.
(b) Guideline documents published under this section will provide
information for the development of State plans, such as:
(1) Information concerning known or suspected endangerment of public
health or welfare caused, or contributed to, by the designated
pollutant.
(2) A description of systems of emission reduction which, in the
judgment of the Administrator, have been adequately demonstrated.
(3) Information on the degree of emission reduction which is
achievable with each system, together with information on the costs and
environmental effects of applying each system to designated facilities.
(4) Incremental periods of time normally expected to be necessary
for the design, installation, and startup of identified control systems.
(5) An emission guideline that reflects the application of the best
system of emission reduction (considering the cost of such reduction)
that has been adequately demonstrated for designated facilities, and the
time within which compliance with emission standards of equivalent
stringency can be achieved. The Administrator will specify different
emission guidelines or compliance times or both for different sizes,
types, and classes of designated facilities when costs of control,
physical limitations, geographical location, or similar factors make
subcategorization appropriate. (6) Such other available information as
the Administrator determines may contribute to the formulation of State
plans.
(c) Except as provided in paragraph (d)(1) of this section, the
emission guidelines and compliance times referred to in paragraph (b)(5)
of this section will be proposed for comment upon publication of the
draft guideline document, and after consideration of comments will be
promulgated in subpart C of this part with such modifications as may be
appropriate.
(d)(1) If the Administrator determines that a designated pollutant
may cause or contribute to endangerment of public welfare, but that
adverse effects on public health have not been demonstrated, he will
include the determination in the draft guideline document and in the
Federal Register notice of its availability. Except as provided in
paragraph (d)(2) of this section, paragraph (c) of this section shall be
inapplicable in such cases.
(2) If the Administrator determines at any time on the basis of new
information that a prior determination under paragraph (d)(1) of this
section is incorrect or no longer correct, he will publish notice of the
determination in the Federal Register, revise the guideline document as
necessary under paragraph (a) of this section, and propose and
promulgate emission guidelines and compliance times under paragraph (c)
of this section.
[40 FR 53346, Nov. 17, 1975, as amended at 54 FR 52189, Dec. 20, 1989]
Sec. 60.23 Adoption and submittal of State plans; public hearings.
(a)(1) Unless otherwise specified in the applicable subpart, within
9 months after notice of the availability of a final guideline document
is published under Sec. 60.22(a), each State shall adopt and submit to
the Administrator, in accordance with Sec. 60.4 of subpart A of this
part, a plan for the control of the designated pollutant to which the
guideline document applies.
(2) Within nine months after notice of the availability of a final
revised guideline document is published as provided in Sec. 60.22(d)(2),
each State shall adopt and submit to the Administrator any plan revision
necessary to meet the requirements of this subpart.
(b) If no designated facility is located within a State, the State
shall submit a letter of certification to that effect to the
Administrator within the time specified in paragraph (a) of this
section. Such certification shall exempt
[[Page 68]]
the State from the requirements of this subpart for that designated
pollutant.
(c)(1) Except as provided in paragraphs (c)(2) and (c)(3) of this
section, the State shall, prior to the adoption of any plan or revision
thereof, conduct one or more public hearings within the State on such
plan or plan revision.
(2) No hearing shall be required for any change to an increment of
progress in an approved compliance schedule unless the change is likely
to cause the facility to be unable to comply with the final compliance
date in the schedule.
(3) No hearing shall be required on an emission standard in effect
prior to the effective date of this subpart if it was adopted after a
public hearing and is at least as stringent as the corresponding
emission guideline specified in the applicable guideline document
published under Sec. 60.22(a).
(d) Any hearing required by paragraph (c) of this section shall be
held only after reasonable notice. Notice shall be given at least 30
days prior to the date of such hearing and shall include:
(1) Notification to the public by prominently advertising the date,
time, and place of such hearing in each region affected;
(2) Availability, at the time of public announcement, of each
proposed plan or revision thereof for public inspection in at least one
location in each region to which it will apply;
(3) Notification to the Administrator;
(4) Notification to each local air pollution control agency in each
region to which the plan or revision will apply; and
(5) In the case of an interstate region, notification to any other
State included in the region.
(e) The State shall prepare and retain, for a minimum of 2 years, a
record of each hearing for inspection by any interested party. The
record shall contain, as a minimum, a list of witnesses together with
the text of each presentation.
(f) The State shall submit with the plan or revision:
(1) Certification that each hearing required by paragraph (c) of
this section was held in accordance with the notice required by
paragraph (d) of this section; and
(2) A list of witnesses and their organizational affiliations, if
any, appearing at the hearing and a brief written summary of each
presentation or written submission.
(g) Upon written application by a State agency (through the
appropriate Regional Office), the Administrator may approve State
procedures designed to insure public participation in the matters for
which hearings are required and public notification of the opportunity
to participate if, in the judgment of the Administrator, the procedures,
although different from the requirements of this subpart, in fact
provide for adequate notice to and participation of the public. The
Administrator may impose such conditions on his approval as he deems
necessary. Procedures approved under this section shall be deemed to
satisfy the requirements of this subpart regarding procedures for public
hearings.
[40 FR 53346, Nov. 17, 1975, as amended at 60 FR 65414, Dec. 19, 1995]
Sec. 60.24 Emission standards and compliance schedules.
(a) Each plan shall include emission standards and compliance
schedules.
(b)(1) Emission standards shall prescribe allowable rates of
emissions except when it is clearly impracticable. Such cases will be
identified in the guideline documents issued under Sec. 60.22. Where
emission standards prescribing equipment specifications are established,
the plan shall, to the degree possible, set forth the emission
reductions achievable by implementation of such specifications, and may
permit compliance by the use of equipment determined by the State to be
equivalent to that prescribed.
(2) Test methods and procedures for determining compliance with the
emission standards shall be specified in the plan. Methods other than
those specified in appendix A to this part may be specified in the plan
if shown to be equivalent or alternative methods as defined in Sec. 60.2
(t) and (u).
(3) Emission standards shall apply to all designated facilities
within the State. A plan may contain emission
[[Page 69]]
standards adopted by local jurisdictions provided that the standards are
enforceable by the State.
(c) Except as provided in paragraph (f) of this section, where the
Administrator has determined that a designated pollutant may cause or
contribute to endangerment of public health, emission standards shall be
no less stringent than the corresponding emission guideline(s) specified
in subpart C of this part, and final compliance shall be required as
expeditiously as practicable but no later than the compliance times
specified in subpart C of this part.
(d) Where the Administrator has determined that a designated
pollutant may cause or contribute to endangerment of public welfare but
that adverse effects on public health have not been demonstrated, States
may balance the emission guidelines, compliance times, and other
information provided in the applicable guideline document against other
factors of public concern in establishing emission standards, compliance
schedules, and variances. Appropriate consideration shall be given to
the factors specified in Sec. 60.22(b) and to information presented at
the public hearing(s) conducted under Sec. 60.23(c).
(e)(1) Any compliance schedule extending more than 12 months from
the date required for submittal of the plan must include legally
enforceable increments of progress to achieve compliance for each
designated facility or category of facilities. Unless otherwise
specified in the applicable subpart, increments of progress must
include, where practicable, each increment of progress specified in
Sec. 60.21(h) and must include such additional increments of progress as
may be necessary to permit close and effective supervision of progress
toward final compliance.
(2) A plan may provide that compliance schedules for individual
sources or categories of sources will be formulated after plan
submittal. Any such schedule shall be the subject of a public hearing
held according to Sec. 60.23 and shall be submitted to the Administrator
within 60 days after the date of adoption of the schedule but in no case
later than the date prescribed for submittal of the first semiannual
report required by Sec. 60.25(e).
(f) Unless otherwise specified in the applicable subpart on a case-
by-case basis for particular designated facilities or classes of
facilities, States may provide for the application of less stringent
emissions standards or longer compliance schedules than those otherwise
required by paragraph (c) of this section, provided that the State
demonstrates with respect to each such facility (or class of
facilities):
(1) Unreasonable cost of control resulting from plant age, location,
or basic process design;
(2) Physical impossibility of installing necessary control
equipment; or
(3) Other factors specific to the facility (or class of facilities)
that make application of a less stringent standard or final compliance
time significantly more reasonable.
(g) Nothing in this subpart shall be construed to preclude any State
or political subdivision thereof from adopting or enforcing (1) emission
standards more stringent than emission guidelines specified in subpart C
of this part or in applicable guideline documents or (2) compliance
schedules requiring final compliance at earlier times than those
specified in subpart C or in applicable guideline documents.
[40 FR 53346, Nov. 17, 1975, as amended at 60 FR 65414, Dec. 19, 1995;
65 FR 76384, Dec. 6, 2000]
Sec. 60.25 Emission inventories, source surveillance, reports.
(a) Each plan shall include an inventory of all designated
facilities, including emission data for the designated pollutants and
information related to emissions as specified in appendix D to this
part. Such data shall be summarized in the plan, and emission rates of
designated pollutants from designated facilities shall be correlated
with applicable emission standards. As used in this subpart,
``correlated'' means presented in such a manner as to show the
relationship between measured or estimated amounts of emissions and the
amounts of such emissions allowable under applicable emission standards.
(b) Each plan shall provide for monitoring the status of compliance
with
[[Page 70]]
applicable emission standards. Each plan shall, as a minimum, provide
for:
(1) Legally enforceable procedures for requiring owners or operators
of designated facilities to maintain records and periodically report to
the State information on the nature and amount of emissions from such
facilities, and/or such other information as may be necessary to enable
the State to determine whether such facilities are in compliance with
applicable portions of the plan.
(2) Periodic inspection and, when applicable, testing of designated
facilities.
(c) Each plan shall provide that information obtained by the State
under paragraph (b) of this section shall be correlated with applicable
emission standards (see Sec. 60.25(a)) and made available to the general
public.
(d) The provisions referred to in paragraphs (b) and (c) of this
section shall be specifically identified. Copies of such provisions
shall be submitted with the plan unless:
(1) They have been approved as portions of a preceding plan
submitted under this subpart or as portions of an implementation plan
submitted under section 110 of the Act, and
(2) The State demonstrates:
(i) That the provisions are applicable to the designated
pollutant(s) for which the plan is submitted, and
(ii) That the requirements of Sec. 60.26 are met.
(e) The State shall submit reports on progress in plan enforcement
to the Administrator on an annual (calendar year) basis, commencing with
the first full report period after approval of a plan or after
promulgation of a plan by the Administrator. Information required under
this paragraph must be included in the annual report required by
Sec. 51.321 of this chapter.
(f) Each progress report shall include:
(1) Enforcement actions initiated against designated facilities
during the reporting period, under any emission standard or compliance
schedule of the plan.
(2) Identification of the achievement of any increment of progress
required by the applicable plan during the reporting period.
(3) Identification of designated facilities that have ceased
operation during the reporting period.
(4) Submission of emission inventory data as described in paragraph
(a) of this section for designated facilities that were not in operation
at the time of plan development but began operation during the reporting
period.
(5) Submission of additional data as necessary to update the
information submitted under paragraph (a) of this section or in previous
progress reports.
(6) Submission of copies of technical reports on all performance
testing on designated facilities conducted under paragraph (b)(2) of
this section, complete with concurrently recorded process data.
[40 FR 53346, Nov. 17, 1975, as amended at 44 FR 65071, Nov. 9, 1979]
Sec. 60.26 Legal authority.
(a) Each plan shall show that the State has legal authority to carry
out the plan, including authority to:
(1) Adopt emission standards and compliance schedules applicable to
designated facilities.
(2) Enforce applicable laws, regulations, standards, and compliance
schedules, and seek injunctive relief.
(3) Obtain information necessary to determine whether designated
facilities are in compliance with applicable laws, regulations,
standards, and compliance schedules, including authority to require
recordkeeping and to make inspections and conduct tests of designated
facilities.
(4) Require owners or operators of designated facilities to install,
maintain, and use emission monitoring devices and to make periodic
reports to the State on the nature and amounts of emissions from such
facilities; also authority for the State to make such data available to
the public as reported and as correlated with applicable emission
standards.
(b) The provisions of law or regulations which the State determines
provide the authorities required by this section shall be specifically
identified. Copies of such laws or regulations shall be submitted with
the plan unless:
(1) They have been approved as portions of a preceding plan
submitted under this subpart or as portions of an
[[Page 71]]
implementation plan submitted under section 110 of the Act, and
(2) The State demonstrates that the laws or regulations are
applicable to the designated pollutant(s) for which the plan is
submitted.
(c) The plan shall show that the legal authorities specified in this
section are available to the State at the time of submission of the
plan. Legal authority adequate to meet the requirements of paragraphs
(a)(3) and (4) of this section may be delegated to the State under
section 114 of the Act.
(d) A State governmental agency other than the State air pollution
control agency may be assigned responsibility for carrying out a portion
of a plan if the plan demonstrates to the Administrator's satisfaction
that the State governmental agency has the legal authority necessary to
carry out that portion of the plan.
(e) The State may authorize a local agency to carry out a plan, or
portion thereof, within the local agency's jurisdiction if the plan
demonstrates to the Administrator's satisfaction that the local agency
has the legal authority necessary to implement the plan or portion
thereof, and that the authorization does not relieve the State of
responsibility under the Act for carrying out the plan or portion
thereof.
Sec. 60.27 Actions by the Administrator.
(a) The Administrator may, whenever he determines necessary, extend
the period for submission of any plan or plan revision or portion
thereof.
(b) After receipt of a plan or plan revision, the Administrator will
propose the plan or revision for approval or disapproval. The
Administrator will, within four months after the date required for
submission of a plan or plan revision, approve or disapprove such plan
or revision or each portion thereof.
(c) The Administrator will, after consideration of any State hearing
record, promptly prepare and publish proposed regulations setting forth
a plan, or portion thereof, for a State if:
(1) The State fails to submit a plan within the time prescribed;
(2) The State fails to submit a plan revision required by
Sec. 60.23(a)(2) within the time prescribed; or
(3) The Administrator disapproves the State plan or plan revision or
any portion thereof, as unsatisfactory because the requirements of this
subpart have not been met.
(d) The Administrator will, within six months after the date
required for submission of a plan or plan revision, promulgate the
regulations proposed under paragraph (c) of this section with such
modifications as may be appropriate unless, prior to such promulgation,
the State has adopted and submitted a plan or plan revision which the
Administrator determines to be approvable.
(e)(1) Except as provided in paragraph (e)(2) of this section,
regulations proposed and promulgated by the Administrator under this
section will prescribe emission standards of the same stringency as the
corresponding emission guideline(s) specified in the final guideline
document published under Sec. 60.22(a) and will require final compliance
with such standards as expeditiously as practicable but no later than
the times specified in the guideline document.
(2) Upon application by the owner or operator of a designated
facility to which regulations proposed and promulgated under this
section will apply, the Administrator may provide for the application of
less stringent emission standards or longer compliance schedules than
those otherwise required by this section in accordance with the criteria
specified in Sec. 60.24(f).
(f) Prior to promulgation of a plan under paragraph (d) of this
section, the Administrator will provide the opportunity for at least one
public hearing in either:
(1) Each State that failed to hold a public hearing as required by
Sec. 60.23(c); or
(2) Washington, DC or an alternate location specified in the Federal
Register.
[40 FR 53346, Nov. 17, 1975, as amended at 65 FR 76384, Dec. 6, 2000]
Sec. 60.28 Plan revisions by the State.
(a) Plan revisions which have the effect of delaying compliance with
applicable emission standards or increments of progress or of
establishing less stringent emission standards shall be submitted to the
Administrator within 60
[[Page 72]]
days after adoption in accordance with the procedures and requirements
applicable to development and submission of the original plan.
(b) More stringent emission standards, or orders which have the
effect of accelerating compliance, may be submitted to the Administrator
as plan revisions in accordance with the procedures and requirements
applicable to development and submission of the original plan.
(c) A revision of a plan, or any portion thereof, shall not be
considered part of an applicable plan until approved by the
Administrator in accordance with this subpart.
Sec. 60.29 Plan revisions by the Administrator.
After notice and opportunity for public hearing in each affected
State, the Administrator may revise any provision of an applicable plan
if:
(a) The provision was promulgated by the Administrator, and
(b) The plan, as revised, will be consistent with the Act and with
the requirements of this subpart.
Subpart C--Emission Guidelines and Compliance Times
Sec. 60.30 Scope.
The following subparts contain emission guidelines and compliance
times for the control of certain designated pollutants in accordance
with section 111(d) and section 129 of the Clean Air Act and subpart B
of this part.
(a) Subpart Ca--[Reserved]
(b) Subpart Cb--Municipal Waste Combustors.
(c) Subpart Cc--Municipal Solid Waste Landfills.
(d) Subpart Cd--Sulfuric Acid Production Plants.
(e) Subpart Ce--Hospital/Medical/Infectious Waste Incinerators.
[62 FR 48379, Sept. 15, 1997]
Sec. 60.31 Definitions.
Terms used but not defined in this subpart have the meaning given
them in the Act and in subparts A and B of this part.
[42 FR 55797, Oct. 18, 1977]
Subpart Ca [Reserved]
Subpart Cb--Emissions Guidelines and Compliance Times for Large
Municipal Waste Combustors That are Constructed on or Before September
20, 1994
Source: 60 FR 65415, Dec. 19, 1995, unless otherwise noted.
Sec. 60.30b Scope.
This subpart contains emission guidelines and compliance schedules
for the control of certain designated pollutants from certain municipal
waste combustors in accordance with section 111(d) and section 129 of
the Clean Air Act and subpart B of this part. The provisions in these
emission guidelines supersede the provisions of Sec. 60.24(f) of subpart
B of this part.
Sec. 60.31b Definitions.
Terms used but not defined in this subpart have the meaning given
them in the Clean Air Act and subparts A, B, and Eb of this part.
Municipal waste combustor plant means one or more designated
facilities (as defined in Sec. 60.32b) at the same location.
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25,
1997]
Sec. 60.32b Designated facilities.
(a) The designated facility to which these guidelines apply is each
municipal waste combustor unit with a combustion capacity greater than
250 tons per day of municipal solid waste for which construction was
commenced on or before September 20, 1994.
(b) Any municipal waste combustion unit that is capable of
combusting more than 250 tons per day of municipal solid waste and is
subject to a federally enforceable permit limiting the maximum amount of
municipal solid waste that may be combusted in the unit to less than or
equal to 11 tons per day is not subject to this subpart if the owner or
operator:
(1) Notifies the EPA Administrator of an exemption claim,
[[Page 73]]
(2) Provides a copy of the federally enforceable permit that limits
the firing of municipal solid waste to less than 11 tons per day, and
(3) Keeps records of the amount of municipal solid waste fired on a
daily basis.
(c) Physical or operational changes made to an existing municipal
waste combustor unit primarily for the purpose of complying with
emission guidelines under this subpart are not considered in determining
whether the unit is a modified or reconstructed facility under subpart
Ea or subpart Eb of this part.
(d) A qualifying small power production facility, as defined in
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that
burns homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy is
not subject to this subpart if the owner or operator of the facility
notifies the EPA Administrator of this exemption and provides data
documenting that the facility qualifies for this exemption.
(e) A qualifying cogeneration facility, as defined in section
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns
homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy and
steam or forms of useful energy (such as heat) that are used for
industrial, commercial, heating, or cooling purposes, is not subject to
this subpart if the owner or operator of the facility notifies the EPA
Administrator of this exemption and provides data documenting that the
facility qualifies for this exemption.
(f) Any unit combusting a single-item waste stream of tires is not
subject to this subpart if the owner or operator of the unit:
(1) Notifies the EPA Administrator of an exemption claim, and
(2) Provides data documenting that the unit qualifies for this
exemption.
(g) Any unit required to have a permit under section 3005 of the
Solid Waste Disposal Act is not subject to this subpart.
(h) Any materials recovery facility (including primary or secondary
smelters) that combusts waste for the primary purpose of recovering
metals is not subject to this subpart.
(i) Any cofired combustor, as defined under Sec. 60.51b of subpart
Eb of this part, that meets the capacity specifications in paragraph (a)
of this section is not subject to this subpart if the owner or operator
of the cofired combustor:
(1) Notifies the EPA Administrator of an exemption claim,
(2) Provides a copy of the federally enforceable permit (specified
in the definition of cofired combustor in this section), and
(3) Keeps a record on a calendar quarter basis of the weight of
municipal solid waste combusted at the cofired combustor and the weight
of all other fuels combusted at the cofired combustor.
(j) Air curtain incinerators, as defined under Sec. 60.51b of
subpart Eb of this part, that meet the capacity specifications in
paragraph (a) of this section, and that combust a fuel stream composed
of 100 percent yard waste are exempt from all provisions of this subpart
except the opacity standard under Sec. 60.37b, the testing procedures
under Sec. 60.38b, and the reporting and recordkeeping provisions under
Sec. 60.39b.
(k) Air curtain incinerators that meet the capacity specifications
in paragraph (a) of this section and that combust municipal solid waste
other than yard waste are subject to all provisions of this subpart.
(l) Pyrolysis/combustion units that are an integrated part of a
plastics/rubber recycling unit (as defined in Sec. 60.51b) are not
subject to this subpart if the owner or operator of the plastics/rubber
recycling unit keeps records of the weight of plastics, rubber, and/or
rubber tires processed on a calendar quarter basis; the weight of
chemical plant feedstocks and petroleum refinery feedstocks produced and
marketed on a calendar quarter basis; and the name and address of the
purchaser of the feedstocks. The combustion of gasoline, diesel fuel,
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke,
liquified petroleum gas, propane, or butane produced by chemical plants
[[Page 74]]
or petroleum refineries that use feedstocks produced by plastics/rubber
recycling units are not subject to this subpart.
(m) Cement kilns firing municipal solid waste are not subject to
this subpart.
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25,
1997]
Sec. 60.33b Emission guidelines for municipal waste combustor metals, acid gases, organics, and nitrogen oxides.
(a) The emission limits for municipal waste combustor metals are
specified in paragraphs (a)(1) through (a)(3) of this section.
(1) For approval, a State plan shall include emission limits for
particulate matter and opacity at least as protective as the emission
limits for particulate matter and opacity specified in paragraphs
(a)(1)(i) through (a)(1)(iii) of this section.
(i) The emission limit for particulate matter contained in the gases
discharged to the atmosphere from a designated facility is 27 milligrams
per dry standard cubic meter, corrected to 7 percent oxygen.
(ii) [Reserved]
(iii) The emission limit for opacity exhibited by the gases
discharged to the atmosphere from a designated facility is 10 percent
(6-minute average).
(2) For approval, a State plan shall include emission limits for
cadmium and lead at least as protective as the emission limits for
cadmium and lead specified in paragraphs (a)(2)(i) through (a)(2)(iv) of
this section.
(i) The emission limit for cadmium contained in the gases discharged
to the atmosphere from a designated facility is 0.040 milligrams per dry
standard cubic meter, corrected to 7 percent oxygen.
(ii) [Reserved]
(iii) The emission limit for lead contained in the gases discharged
to the atmosphere from a designated facility is 0.49 milligrams per dry
standard cubic meter, corrected to 7 percent oxygen.
(iv) [Reserved]
(3) For approval, a State plan shall include emission limits for
mercury at least as protective as the emission limits specified in this
paragraph. The emission limit for mercury contained in the gases
discharged to the atmosphere from a designated facility is 0.080
milligrams per dry standard cubic meter or 15 percent of the potential
mercury emission concentration (85-percent reduction by weight),
corrected to 7 percent oxygen, whichever is less stringent.
(4) For approval, a State plan shall be submitted by August 25, 1998
and shall include an emission limit for lead at least as protective as
the emission limit for lead specified in this paragraph. The emission
limit for lead contained in the gases discharged to the atmosphere from
a designated facility is 0.44 milligrams per dry standard cubic meter,
corrected to 7 percent oxygen.
(b) The emission limits for municipal waste combustor acid gases,
expressed as sulfur dioxide and hydrogen chloride, are specified in
paragraphs (b)(1) and (b)(2) of this section.
(1) For approval, a State plan shall include emission limits for
sulfur dioxide at least as protective as the emission limits for sulfur
dioxide specified in paragraphs (b)(1)(i) and (b)(1)(ii) of this
section.
(i) The emission limit for sulfur dioxide contained in the gases
discharged to the atmosphere from a designated facility is 31 parts per
million by volume or 25 percent of the potential sulfur dioxide emission
concentration (75-percent reduction by weight or volume), corrected to 7
percent oxygen (dry basis), whichever is less stringent. Compliance with
this emission limit is based on a 24-hour daily geometric mean.
(ii) [Reserved]
(2) For approval, a State plan shall include emission limits for
hydrogen chloride at least as protective as the emission limits for
hydrogen chloride specified in paragraphs (b)(2)(i) and (b)(2)(ii) of
this section.
(i) The emission limit for hydrogen chloride contained in the gases
discharged to the atmosphere from a designated facility is 31 parts per
million by volume or 5 percent of the potential hydrogen chloride
emission concentration (95-percent reduction by weight or
[[Page 75]]
volume), corrected to 7 percent oxygen (dry basis), whichever is less
stringent.
(ii) [Reserved]
(3) For approval, a State plan shall be submitted by August 25, 1998
and shall include emission limits for sulfur dioxide and hydrogen
chloride at least as protective as the emission limits specified in
paragraphs (b)(3)(i) and (b)(3)(ii) of this section.
(i) The emission limit for sulfur dioxide contained in the gases
discharged to the atmosphere from a designated facility is 29 parts per
million by volume or 25 percent of the potential sulfur dioxide emission
concentration (75-percent reduction by weight or volume), corrected to 7
percent oxygen (dry basis), whichever is less stringent. Compliance with
this emission limit is based on a 24-hour daily geometric mean.
(ii) The emission limit for hydrogen chloride contained in the gases
discharged to the atmosphere from a designated facility is 29 parts per
million by volume or 5 percent of the potential hydrogen chloride
emission concentration (95-percent reduction by weight or volume),
corrected to 7 percent oxygen (dry basis), whichever is less stringent.
(c) The emission limits for municipal waste combustor organics,
expressed as total mass dioxins/furans, are specified in paragraphs
(c)(1) and (c)(2) of this section.
(1) For approval, a State plan shall include an emission limit for
dioxins/furans contained in the gases discharged to the atmosphere from
a designated facility at least as protective as the emission limit for
dioxins/furans specified in either paragraph (c)(1)(i) or (c)(1)(ii) of
this section, as applicable.
(i) The emission limit for designated facilities that employ an
electrostatic precipitator-based emission control system is 60 nanograms
per dry standard cubic meter (total mass), corrected to 7 percent
oxygen.
(ii) The emission limit for designated facilities that do not employ
an electrostatic precipitator-based emission control system is 30
nanograms per dry standard cubic meter (total mass), corrected to 7
percent oxygen.
(2) [Reserved]
(d) For approval, a State plan shall include emission limits for
nitrogen oxides at least as protective as the emission limits listed in
table 1 of this subpart for designated facilities. Table 1 provides
emission limits for the nitrogen oxides concentration level for each
type of designated facility.
Table 1--Nitrogen Oxides Guidelines for Designated Facilities
------------------------------------------------------------------------
Nitrogen
oxides
emission
Municipal waste combustor technology limit (parts
per million
by volume)
\a\
------------------------------------------------------------------------
Mass burn waterwall....................................... 205
Mass burn rotary waterwall................................ 250
Refuse-derived fuel combustor............................. 250
Fluidized bed combustor................................... 240
Mass burn refractory combustors........................... no limit
------------------------------------------------------------------------
\a\ Corrected to 7 percent oxygen, dry basis.
(1) A State plan may allow nitrogen oxides emissions averaging as
specified in paragraphs (d)(1)(i) through (d)(1)(v) of this section.
(i) The owner or operator of a municipal waste combustor plant may
elect to implement a nitrogen oxides emissions averaging plan for the
designated facilities that are located at that plant and that are
subject to subpart Cb, except as specified in paragraphs (d)(1)(i)(A)
and (d)(1)(i)(B) of this section.
(A) Municipal waste combustor units subject to subpart Ea or Eb
cannot be included in the emissions averaging plan.
(B) Mass burn refractory municipal waste combustor units and other
municipal waste combustor technologies not listed in paragraph
(d)(1)(iii) of this section may not be included in the emissions
averaging plan.
(ii) The designated facilities included in the nitrogen oxides
emissions averaging plan must be identified in the initial compliance
report specified in Sec. 60.59b(f) or in the annual report specified in
Sec. 60.59b(g), as applicable, prior to implementing the averaging plan.
The designated facilities being included in the averaging plan may be
redesignated each calendar year. Partial year redesignation is allowable
with State approval.
(iii) To implement the emissions averaging plan, the average daily
(24-hour) nitrogen oxides emission concentration level for gases
discharged
[[Page 76]]
from the designated facilities being included in the emissions averaging
plan must be no greater than the levels specified in table 2 of this
subpart. Table 2 provides emission limits for the nitrogen oxides
concentration level for each type of designated facility.
Table 2--Nitrogen Oxides Limits For Existing Designated Facilities
Included in an Emissions Averaging Plan at a Municpial Waste Combustor
Planta
------------------------------------------------------------------------
Nitrogen
oxides
emission
Municipal waste combustor technology limit (parts
per million
by volume)b
------------------------------------------------------------------------
Mass burn waterwall....................................... 185
Mass burn rotary waterwall................................ 220
Refuse-derived fuel combustor............................. 230
Fluidized bed combustor................................... 220
------------------------------------------------------------------------
a Mass burn refractory municipal waste combustors and other MWC
technologies not listed above may not be included in an emissions
averaging plan.
b Corrected to 7 percent oxygen, dry basis.
(iv) Under the emissions averaging plan, the average daily nitrogen
oxides emissions specified in paragraph (d)(1)(iii) of this section
shall be calculated using equation (1). Designated facilities that are
offline shall not be included in calculating the average daily nitrogen
oxides emission level.
[GRAPHIC] [TIFF OMITTED] TR19DE95.000
where:
NOX 24-hr=24-hr daily average nitrogen oxides emission
concentration level for the emissions averaging plan (parts per million
by volume corrected to 7 percent oxygen).
NOX i-hr=24-hr daily average nitrogen oxides emission
concentration level for designated facility i (parts per million by
volume, corrected to 7 percent oxygen), calculated according to the
procedures in Sec. 60.58b(h) of this subpart.
Si=maximum demonstrated municipal waste combustor unit load
for designated facility i (pounds per hour steam or feedwater flow as
determined in the most recent dioxin/furan performance test).
h=total number of designated facilities being included in the daily
emissions average.
(v) For any day in which any designated facility included in the
emissions averaging plan is offline, the owner or operator of the
municipal waste combustor plant must demonstrate compliance according to
either paragraph (d)(1)(v)(A) of this section or both paragraphs
(d)(1)(v)(B) and (d)(1)(v)(C) of this section.
(A) Compliance with the applicable limits specified in table 2 of
this subpart shall be demonstrated using the averaging procedure
specified in paragraph (d)(1)(iv) of this section for the designated
facilities that are online.
(B) For each of the designated facilities included in the emissions
averaging plan, the nitrogen oxides emissions on a daily average basis
shall be calculated and shall be equal to or less than the maximum daily
nitrogen oxides emission level achieved by that designated facility on
any of the days during which the emissions averaging plan was achieved
with all designated facilities online during the most recent calendar
quarter. The requirements of this paragraph do not apply during the
first quarter of operation under the emissions averaging plan.
(C) The average nitrogen oxides emissions (kilograms per day)
calculated according to paragraph (d)(1)(v)(C)(2) of this section shall
not exceed the average nitrogen oxides emissions (kilograms per day)
calculated according to paragraph (d)(1)(v)(C)(1) of this section.
(1) For all days during which the emissions averaging plan was
implemented and achieved and during which all designated facilities were
online, the average nitrogen oxides emissions shall be calculated. The
average nitrogen oxides emissions (kilograms per day) shall be
calculated on a calendar year basis according to paragraphs
(d)(1)(v)(C)(1)(i) through (d)(1)(v)(C)(1)(iii) of this section.
(i) For each designated facility included in the emissions averaging
plan, the daily amount of nitrogen oxides emitted (kilograms per day)
shall be calculated based on the hourly nitrogen oxides data required
under Sec. 60.38b(a) and specified under Sec. 60.58b(h)(5) of subpart Eb
of this part,
[[Page 77]]
the flue gas flow rate determined using table 19-1 of EPA Reference
Method 19 or a State-approved method, and the hourly average steam or
feedwater flow rate.
(ii) The daily total nitrogen oxides emissions shall be calculated
as the sum of the daily nitrogen oxides emissions from each designated
facility calculated under paragraph (d)(1)(v)(C)(1)(i) of this section.
(iii) The average nitrogen oxides emissions (kilograms per day) on a
calendar year basis shall be calculated as the sum of all daily total
nitrogen oxides emissions calculated under paragraph (d)(1)(v)(C)(1)(ii)
of this section divided by the number of calendar days for which a daily
total was calculated.
(2) For all days during which one or more of the designated
facilities under the emissions averaging plan was offline, the average
nitrogen oxides emissions shall be calculated. The average nitrogen
oxides emissions (kilograms per day) shall be calculated on a calendar
year basis according to paragraphs (d)(1)(v)(C)(2)(i) through
(d)(1)(v)(C)(2)(iii) of this section.
(i) For each designated facility included in the emissions averaging
plan, the daily amount of nitrogen oxides emitted (kilograms per day)
shall be calculated based on the hourly nitrogen oxides data required
under Sec. 60.38b(a) and specified under Sec. 60.58b(h)(5) of subpart Eb
of this part, the flue gas flow rate determined using table 19-1 of EPA
Reference Method 19 or a State-approved method, and the hourly average
steam or feedwater flow rate.
(ii) The daily total nitrogen oxides emissions shall be calculated
as the sum of the daily nitrogen oxides emissions from each designated
facility calculated under paragraph (d)(1)(v)(C)(2)(i) of this section.
(iii) The average nitrogen oxides emissions (kilograms per day) on a
calendar year basis shall be calculated as the sum of all daily total
nitrogen oxides emissions calculated under paragraph (d)(1)(v)(C)(2)(ii)
of this section divided by the number of calendar days for which a daily
total was calculated.
(2) A State plan may establish a program to allow owners or
operators of municipal waste combustor plants to engage in trading of
nitrogen oxides emission credits. A trading program must be approved by
the Administrator before implementation.
(3) For approval, a State plan shall be submitted by August 25, 1998
and shall include emission limits for nitrogen oxides from fluidized bed
combustors at least as protective as the emission limits listed in
paragraphs (d)(3)(i) and (d)(3)(ii) of this section.
(i) The emission limit for nitrogen oxides contained in the gases
discharged to the atmosphere from a designated facility that is a
fluidized bed combustor is 180 parts per million by volume, corrected to
7 percent oxygen.
(ii) If a State plan allows nitrogen oxides emissions averaging as
specified in paragraphs (d)(1)(i) through (d)(1)(v) of this section, the
emission limit for nitrogen oxides contained in the gases discharged to
the atmosphere from a designated facility that is a fluidized bed
combustor is 165 parts per million by volume, corrected to 7 percent
oxygen.
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25,
1997]
Sec. 60.34b Emission guidelines for municipal waste combustor operating practices.
(a) For approval, a State plan shall include emission limits for
carbon monoxide at least as protective as the emission limits for carbon
monoxide listed in table 3 of this subpart. Table 3 provides emission
limits for the carbon monoxide concentration level for each type of
designated facility.
Table 3.--Municipal Waste Combustor Operating Guidelines
------------------------------------------------------------------------
Carbon
monoxide
emissions
Municipal waste combustor technology level Averaging
(parts per time (hrs)b
million by
volume)a
------------------------------------------------------------------------
Mass burn waterwall........................... 100 4
Mass burn refractory.......................... 100 4
[[Page 78]]
Mass burn rotary refractory................... 100 24
Mass burn rotary waterwall.................... 250 24
Modular starved air........................... 50 4
Modular excess air............................ 50 4
Refuse-derived fuel stoker.................... 200 24
Buddling fluidized bed combustor.............. 100 4
Circulating fluidized bed combustor........... 100 4
Pulverized coal/refuse-derived fuel mixed fuel- 150 4
fired combustor..............................
Spreader stoker coal/refuse-derived fuel mixed 200 24
fuel-fired combustor.........................
------------------------------------------------------------------------
a Measured at the combustor outlet in conjunction with a measurement of
oxygen concentration, corrected to 7 percent oxygen, dry basis.
Calculated as an arithmetic average.
b Averaging times are 4-hour or 24-hour block averages.
(b) For approval, a State plan shall include requirements for
municipal waste combustor operating practices at least as protective as
those requirements listed in Sec. 60.53b(b) and (c) of subpart Eb of
this part.
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25,
1997]
Sec. 60.35b Emission guidelines for municipal waste combustor operator training and certification.
For approval, a State plan shall include requirements for designated
facilities for municipal waste combustor operator training and
certification at least as protective as those requirements listed in
Sec. 60.54b of subpart Eb of this part. The State plan shall require
compliance with these requirements according to the schedule specified
in Sec. 60.39b(c)(4).
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, Aug. 25, 1997]
Sec. 60.36b Emission guidelines for municipal waste combustor fugitive ash emissions.
For approval, a State plan shall include requirements for municipal
waste combustor fugitive ash emissions at least as protective as those
requirements listed in Sec. 60.55b of subpart Eb of this part.
Sec. 60.37b Emission guidelines for air curtain incinerators.
For approval, a State plan shall include emission limits for opacity
for air curtain incinerators at least as protective as those listed in
Sec. 60.56b of subpart Eb of this part.
Sec. 60.38b Compliance and performance testing.
(a) For approval, a State plan shall include the performance testing
methods listed in Sec. 60.58b of subpart Eb of this part, as applicable,
except as provided for under Sec. 60.24(b)(2) of subpart B of this part
and paragraphs (b) and (c) of this section.
(b) For approval, a State plan shall include for designated
facilities the alternative performance testing schedule for dioxins/
furans specified in Sec. 60.58b(g)(5)(iii) of subpart Eb of this part,
as applicable, for those designated facilities that achieve a dioxin/
furan emission level less than or equal to 15 nanograms per dry standard
cubic meter total mass, corrected to 7 percent oxygen.
(c) [Reserved]
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, Aug. 25, 1997]
Sec. 60.39b Reporting and recordkeeping guidelines and compliance schedules.
(a) For approval, a State plan shall include the reporting and
recordkeeping provisions listed in Sec. 60.59b of subpart Eb of this
part, as applicable, except for the siting requirements under
Sec. 60.59b(a), (b)(5), and (d)(11) of subpart Eb of this part.
(b) Not later than December 19, 1996, each State in which a
designated facility is located shall submit to the EPA Administrator a
plan to implement and
[[Page 79]]
enforce all provisions of this subpart except those specified under
Sec. 60.33b (a)(4), (b)(3), and (d)(3). The compliance schedule
specified in this paragraph is in accordance with section 129(b)(2) of
the Act and supersedes the compliance schedule provided in
Sec. 60.23(a)(1) of subpart B of this part.
(c) For approval, a State plan shall include the compliance
schedules specified in paragraphs (c)(1) through (c)(5) of this section.
(1) A State plan shall allow designated facilities to comply with
all requirements of a State plan (or close) within 1 year after approval
of the State plan, except as provided by paragraph (c)(1)(i) and
(c)(1)(ii) of this section.
(i) A State plan that allows designated facilities more than 1 year
but less than 3 years following the date of issuance of a revised
construction or operation permit, if a permit modification is required,
or more than 1 year but less than 3 years following approval of the
State plan, if a permit modification is not required, shall include
measurable and enforceable incremental steps of progress toward
compliance. Suggested measurable and enforceable activities are
specified in paragraphs (c)(1)(i)(A) through (c)(1)(i)(J) of this
section.
(A) Date for obtaining services of an architectural and engineering
firm regarding the air pollution control device(s);
(B) Date for obtaining design drawings of the air pollution control
device(s);
(C) Date for submittal of permit modifications, if necessary;
(D) Date for submittal of the final control plan to the
Administrator. [Sec. 60.21 (h)(1) of subpart B of this part.];
(E) Date for ordering the air pollution control device(s);
(F) Date for obtaining the major components of the air pollution
control device(s);
(G) Date for initiation of site preparation for installation of the
air pollution control device(s);
(H) Date for initiation of installation of the air pollution control
device(s);
(I) Date for initial startup of the air pollution control device(s);
and
(J) Date for initial performance test(s) of the air pollution
control device(s).
(ii) A State plan that allows designated facilities more than 1 year
but up to 3 years after State plan approval to close shall require a
closure agreement. The closure agreement must include the date of plant
closure.
(2) If the State plan requirements for a designated facility include
a compliance schedule longer than 1 year after approval of the State
plan in accordance with paragraph (c)(1)(i) or (c)(1)(ii) of this
section, the State plan submittal (for approval) shall include
performance test results for dioxin/furan emissions for each designated
facility that has a compliance schedule longer than 1 year following the
approval of the State plan, and the performance test results shall have
been conducted during or after 1990. The performance test shall be
conducted according to the procedures in Sec. 60.38b.
(3) [Reserved]
(4) A State plan shall require compliance with the municipal waste
combustor operator training and certification requirements under
Sec. 60.35b according to the schedule specified in paragraphs (c)(4)(i)
through (c)(4)(iii) of this section.
(i) [Reserved]
(ii) For designated facilities, the State plan shall require
compliance with the municipal waste combustor operator training and
certification requirements specified under Sec. 60.54b (a) through (c)
of subpart Eb of this part by the date 6 months after the date of
startup or 12 months after State plan approval, whichever is later.
(iii) For designated facilities, the State plan shall require
compliance with the requirements specified in Sec. 60.54b (d), (f), and
(g) of subpart Eb of this part no later than 6 months after startup or
12 months after State plan approval, whichever is later.
(A) The requirement specified in Sec. 60.54b(d) of subpart Eb of
this part does not apply to chief facility operators, shift supervisors,
and control room operators who have obtained full certification from the
American Society of Mechanical Engineers on or before the date of State
plan approval.
[[Page 80]]
(B) The owner or operator of a designated facility may request that
the EPA Administrator waive the requirement specified in Sec. 60.54b(d)
of subpart Eb of this part for chief facility operators, shift
supervisors, and control room operators who have obtained provisional
certification from the American Society of Mechanical Engineers on or
before the date of State plan approval.
(C) The initial training requirements specified in Sec. 60.54b(f)(1)
of subpart Eb of this part shall be completed no later than the date
specified in paragraph (c)(4)(iii)(C)(1), (c)(4)(iii)(C)(2), or
(c)(4)(iii)(C)(3), of this section whichever is later.
(1) The date 6 months after the date of startup of the affected
facility;
(2) Twelve months after State plan approval; or
(3) The date prior to the day when the person assumes
responsibilities affecting municipal waste combustor unit operation.
(5) A State plan shall require all designated facilities for which
construction, modification, or reconstruction is commenced after June
26, 1987 to comply with the emission limit for mercury specified in
Sec. 60.33b(a)(3) and the emission limit for dioxins/furans specified in
Sec. 60.33b(c)(1) within 1 year following issuance of a revised
construction or operation permit, if a permit modification is required,
or within 1 year following approval of the State plan, whichever is
later.
(d) In the event no plan for implementing the emission guidelines is
approved by EPA, all designated facilities meeting the applicability
requirements under Sec. 60.32b shall be in compliance with all of the
guidelines, except those specified under Sec. 60.33b (a)(4), (b)(3), and
(d)(3), no later than December 19, 2000.
(e) Not later than August 25, 1998, each State in which a designated
facility is operating shall submit to the EPA Administrator a plan to
implement and enforce all provisions of this subpart specified in
Sec. 60.33b (a)(4), (b)(3), and (d)(3).
(f) In the event no plan for implementing the emission guidelines is
approved by EPA, all designated facilities meeting the applicability
requirements under Sec. 60.32b shall be in compliance with all of the
guidelines, including those specified under Sec. 60.33b (a)(4), (b)(3),
and (d)(3), no later than August 26, 2002.
[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25,
1997]
Subpart Cc--Emission Guidelines and Compliance Times for Municipal Solid
Waste Landfills
Source: 61 FR 9919, Mar. 12, 1996, unless otherwise noted.
Sec. 60.30c Scope.
This subpart contains emission guidelines and compliance times for
the control of certain designated pollutants from certain designated
municipal solid waste landfills in accordance with section 111(d) of the
Act and subpart B.
Sec. 60.31c Definitions.
Terms used but not defined in this subpart have the meaning given
them in the Act and in subparts A, B, and WWW of this part.
Municipal solid waste landfill or MSW landfill means an entire
disposal facility in a contiguous geographical space where household
waste is placed in or on land. An MSW landfill may also receive other
types of RCRA Subtitle D wastes such as commercial solid waste,
nonhazardous sludge, conditionally exempt small quantity generator
waste, and industrial solid waste. Portions of an MSW landfill may be
separated by access roads. An MSW landfill may be publicly or privately
owned. An MSW landfill may be a new MSW landfill, an existing MSW
landfill or a lateral expansion.
Sec. 60.32c Designated facilities.
(a) The designated facility to which the guidelines apply is each
existing MSW landfill for which construction, reconstruction or
modification was commenced before May 30, 1991.
(b) Physical or operational changes made to an existing MSW landfill
solely to comply with an emission guideline are not considered a
modification
[[Page 81]]
or reconstruction and would not subject an existing MSW landfill to the
requirements of subpart WWW [see Sec. 60.750 of Subpart WWW].
(c) For purposes of obtaining an operating permit under title V of
the Act, the owner or operator of a MSW landfill subject to this subpart
with a design capacity less than 2.5 million megagrams or 2.5 million
cubic meters is not subject to the requirement to obtain an operating
permit for the landfill under part 70 or 71 of this chapter, unless the
landfill is otherwise subject to either part 70 or 71. For purposes of
submitting a timely application for an operating permit under part 70 or
71, the owner or operator of a MSW landfill subject to this subpart with
a design capacity greater than or equal to 2.5 million megagrams and 2.5
million cubic meters on the effective date of EPA approval of the
State's program under section 111(d) of the Act, and not otherwise
subject to either part 70 or 71, becomes subject to the requirements of
Secs. 70.5(a)(1)(i) or 71.5(a)(1)(i) of this chapter 90 days after the
effective date of such 111(d) program approval, even if the design
capacity report is submitted earlier.
(d) When a MSW landfill subject to this subpart is closed, the owner
or operator is no longer subject to the requirement to maintain an
operating permit under part 70 or 71 of this chapter for the landfill if
the landfill is not otherwise subject to the requirements of either part
70 or 71 and if either of the following conditions are met.
(1) The landfill was never subject to the requirement for a control
system under Sec. 60.33c(c) of this subpart; or
(2) The owner or operator meets the conditions for control system
removal specified in Sec. 60.752(b)(2)(v) of subpart WWW.
[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998]
Sec. 60.33c Emission guidelines for municipal solid waste landfill emissions.
(a) For approval, a State plan shall include control of MSW landfill
emissions at each MSW landfill meeting the following three conditions:
(1) The landfill has accepted waste at any time since November 8,
1987, or has additional design capacity available for future waste
deposition;
(2) The landfill has a design capacity greater than or equal to 2.5
million megagrams and 2.5 million cubic meters. The landfill may
calculate design capacity in either megagrams or cubic meters for
comparison with the exemption values. Any density conversions shall be
documented and submitted with the design capacity report; and
(3) The landfill has a nonmethane organic compound emission rate of
50 megagrams per year or more.
(b) For approval, a State plan shall include the installation of a
collection and control system meeting the conditions provided in
Sec. 60.752(b)(2)(ii) of this part at each MSW landfill meeting the
conditions in paragraph (a) of this section. The State plan shall
include a process for State review and approval of the site-specific
design plans for the gas collection and control system(s).
(c) For approval, a State plan shall include provisions for the
control of collected MSW landfill emissions through the use of control
devices meeting the requirements of paragraph (c)(1), (2), or (3) of
this section, except as provided in Sec. 60.24.
(1) An open flare designed and operated in accordance with the
parameters established in Sec. 60.18; or
(2) A control system designed and operated to reduce NMOC by 98
weight percent; or
(3) An enclosed combustor designed and operated to reduce the outlet
NMOC concentration to 20 parts per million as hexane by volume, dry
basis at 3 percent oxygen, or less.
(d) For approval, a State plan shall require each owner or operator
of an MSW landfill having a design capacity less than 2.5 million
megagrams by mass or 2.5 million cubic meters by volume to submit an
initial design capacity report to the Administrator as provided in
Sec. 60.757(a)(2) of subpart WWW by the date specified in Sec. 60.35c of
this subpart. The landfill may calculate design capacity in either
megagrams or cubic meters for comparison with the exemption values. Any
density conversions shall be documented and submitted with the report.
Submittal of the initial design capacity report shall fulfill the
requirements of this subpart
[[Page 82]]
except as provided in paragraph (d)(1) and (d)(2) of this section.
(1) The owner or operator shall submit an amended design capacity
report as provided in Sec. 60.757(a)(3) of subpart WWW. [Guidance: Note
that if the design capacity increase is the result of a modification, as
defined in Sec. 60.751 of subpart WWW, that was commenced on or after
May 30, 1991, the landfill will become subject to subpart WWW instead of
this subpart. If the design capacity increase is the result of a change
in operating practices, density, or some other change that is not a
modification, the landfill remains subject to this subpart.]
(2) When an increase in the maximum design capacity of a landfill
with an initial design capacity less than 2.5 million megagrams or 2.5
million cubic meters results in a revised maximum design capacity equal
to or greater than 2.5 million megagrams and 2.5 million cubic meters,
the owner or operator shall comply with paragraph (e) of this section.
(e) For approval, a State plan shall require each owner or operator
of an MSW landfill having a design capacity equal to or greater than 2.5
million megagrams and 2.5 million cubic meters to either install a
collection and control system as provided in paragraph (b) of this
section and Sec. 60.752(b)(2) of subpart WWW or calculate an initial
NMOC emission rate for the landfill using the procedures specified in
Sec. 60.34c of this subpart and Sec. 60.754 of subpart WWW. The NMOC
emission rate shall be recalculated annually, except as provided in
Sec. 60.757(b)(1)(ii) of subpart WWW.
(1) If the calculated NMOC emission rate is less than 50 megagrams
per year, the owner or operator shall:
(i) Submit an annual emission report, except as provided for in
Sec. 60.757(b)(1)(ii); and
(ii) Recalculate the NMOC emission rate annually using the
procedures specified in Sec. 60.754(a)(1) of subpart WWW until such time
as the calculated NMOC emission rate is equal to or greater than 50
megagrams per year, or the landfill is closed.
(2)(i) If the NMOC emission rate, upon initial calculation or annual
recalculation required in paragraph (e)(1)(ii) of this section, is equal
to or greater than 50 megagrams per year, the owner or operator shall
install a collection and control system as provided in paragraph (b) of
this section and Sec. 60.752(b)(2) of subpart WWW.
(ii) If the landfill is permanently closed, a closure notification
shall be submitted to the Administrator as provided in Sec. 60.35c of
this subpart and Sec. 60.757(d) of subpart WWW.
[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998; 64
FR 9261, Feb. 24, 1999]
Sec. 60.34c Test methods and procedures.
For approval, a State plan shall include provisions for: the
calculation of the landfill NMOC emission rate listed in Sec. 60.754, as
applicable, to determine whether the landfill meets the condition in
Sec. 60.33c(a)(3); the operational standards in Sec. 60.753; the
compliance provisions in Sec. 60.755; and the monitoring provisions in
Sec. 60.756.
Sec. 60.35c Reporting and recordkeeping guidelines.
For approval, a State plan shall include the recordkeeping and
reporting provisions listed in Secs. 60.757 and 60.758, as applicable,
except as provided under Sec. 60.24.
(a) For existing MSW landfills subject to this subpart the initial
design capacity report shall be submitted no later than 90 days after
the effective date of EPA approval of the State's plan under section
111(d) of the Act.
(b) For existing MSW landfills covered by this subpart with a design
capacity equal to or greater than 2.5 million megagrams and 2.5 million
cubic meters, the initial NMOC emission rate report shall be submitted
no later than 90 days after the effective date of EPA approval of the
State's plan under section 111(d) of the Act.
[61 FR 9919, Mar. 12, 1996, as amended at 64 FR 9262, Feb. 24, 1999]
Sec. 60.36c Compliance times.
(a) Except as provided for under paragraph (b) of this section,
planning, awarding of contracts, and installation of MSW landfill air
emission collection and control equipment capable of
[[Page 83]]
meeting the emission guidelines established under Sec. 60.33c shall be
accomplished within 30 months after the date the initial NMOC emission
rate report shows NMOC emissions equal or exceed 50 megagrams per year.
(b) For each existing MSW landfill meeting the conditions in
Sec. 60.33c(a)(1) and Sec. 60.33c(a)(2) whose NMOC emission rate is less
than 50 megagrams per year on the effective date of the State emission
standard, installation of collection and control systems capable of
meeting emission guidelines in Sec. 60.33c shall be accomplished within
30 months of the date when the condition in Sec. 60.33c(a)(3) is met
(i.e., the date of the first annual nonmethane organic compounds
emission rate which equals or exceeds 50 megagrams per year).
[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998]
Subpart Cd--Emissions Guidelines and Compliance Times for Sulfuric Acid
Production Units
Source: 60 FR 65414, Dec. 19, 1995, unless otherwise noted.
Sec. 60.30d Designated facilities.
Sulfuric acid production units. The designated facility to which
Secs. 60.31d and 60.32d apply is each existing ``sulfuric acid
production unit'' as defined in Sec. 60.81(a) of subpart H of this part.
Sec. 60.31d Emissions guidelines.
Sulfuric acid production units. The emission guideline for
designated facilities is 0.25 grams sulfuric acid mist (as measured by
EPA Reference Method 8 of appendix A of this part) per kilogram (0.5
pounds per ton) of sulfuric acid produced, the production being
expressed as 100 percent sulfuric acid.
Sec. 60.32d Compliance times.
Sulfuric acid production units. Planning, awarding of contracts, and
installation of equipment capable of attaining the level of the emission
guideline established under Sec. 60.31d can be accomplished within 17
months after the effective date of a State emission standard for
sulfuric acid mist.
Subpart Ce--Emission Guidelines and Compliance Times for Hospital/
Medical/Infectious Waste Incinerators
Source: 62 FR 48379, Sept. 15, 1997, unless otherwise noted.
Sec. 60.30e Scope.
This subpart contains emission guidelines and compliance times for
the control of certain designated pollutants from hospital/medical/
infectious waste incinerator(s) (HMIWI) in accordance with sections 111
and 129 of the Clean Air Act and subpart B of this part. The provisions
in these emission guidelines supersede the provisions of Sec. 60.24(f)
of subpart B of this part.
Sec. 60.31e Definitions.
Terms used but not defined in this subpart have the meaning given
them in the Clean Air Act and in subparts A, B, and Ec of this part.
Standard Metropolitan Statistical Area or SMSA means any areas
listed in OMB Bulletin No. 93-17 entitled ``Revised Statistical
Definitions for Metropolitan Areas'' dated June 30, 1993 (incorporated
by reference, see Sec. 60.17).
Sec. 60.32e Designated facilities.
(a) Except as provided in paragraphs (b) through (h) of this
section, the designated facility to which the guidelines apply is each
individual HMIWI for which construction was commenced on or before June
20, 1996.
(b) A combustor is not subject to this subpart during periods when
only pathological waste, low-level radioactive waste, and/or
chemotherapeutic waste (all defined in Sec. 60.51c) is burned, provided
the owner or operator of the combustor:
(1) Notifies the Administrator of an exemption claim; and
(2) Keeps records on a calendar quarter basis of the periods of time
when only pathological waste, low-level radioactive waste, and/or
chemotherapeutic waste is burned.
(c) Any co-fired combustor (defined in Sec. 60.51c) is not subject
to this subpart if the owner or operator of the co-fired combustor:
[[Page 84]]
(1) Notifies the Administrator of an exemption claim;
(2) Provides an estimate of the relative weight of hospital waste,
medical/infectious waste, and other fuels and/or wastes to be combusted;
and
(3) Keeps records on a calendar quarter basis of the weight of
hospital waste and medical/infectious waste combusted, and the weight of
all other fuels and wastes combusted at the co-fired combustor.
(d) Any combustor required to have a permit under Section 3005 of
the Solid Waste Disposal Act is not subject to this subpart.
(e) Any combustor which meets the applicability requirements under
subpart Cb, Ea, or Eb of this part (standards or guidelines for certain
municipal waste combustors) is not subject to this subpart.
(f) Any pyrolysis unit (defined in Sec. 60.51c) is not subject to
this subpart.
(g) Cement kilns firing hospital waste and/or medical/infectious
waste are not subject to this subpart.
(h) Physical or operational changes made to an existing HMIWI unit
solely for the purpose of complying with emission guidelines under this
subpart are not considered a modification and do not result in an
existing HMIWI unit becoming subject to the provisions of subpart Ec
(see Sec. 60.50c).
(i) Beginning September 15, 2000, or on the effective date of an EPA
approved operating permit program under Clean Air Act title V and the
implementing regulations under 40 CFR part 70 in the State in which the
unit is located, whichever date is later, designated facilities subject
to this subpart shall operate pursuant to a permit issued under the EPA-
approved operating permit program.
Sec. 60.33e Emission guidelines.
(a) For approval, a State plan shall include the requirements for
emission limits at least as protective as those requirements listed in
Table 1 of this subpart, except as provided for in paragraph (b) of this
section.
(b) For approval, a State plan shall include the requirements for
emission limits at least as protective as those requirements listed in
Table 2 of this subpart for any small HMIWI which is located more than
50 miles from the boundary of the nearest Standard Metropolitan
Statistical Area (defined in Sec. 60.31e) and which burns less than
2,000 pounds per week of hospital waste and medical/infectious waste.
The 2,000 lb/week limitation does not apply during performance tests.
(c) For approval, a State plan shall include the requirements for
stack opacity at least as protective as Sec. 60.52c(b) of subpart Ec of
this part.
Sec. 60.34e Operator training and qualification guidelines.
For approval, a State plan shall include the requirements for
operator training and qualification at least as protective as those
requirements listed in Sec. 60.53c of subpart Ec of this part. The State
plan shall require compliance with these requirements according to the
schedule specified in Sec. 60.39e(e).
Sec. 60.35e Waste management guidelines.
For approval, a State plan shall include the requirements for a
waste management plan at least as protective as those requirements
listed in Sec. 60.55c of subpart Ec of this part.
Sec. 60.36e Inspection guidelines.
(a) For approval, a State plan shall require that each small HMIWI
subject to the emission limits under Sec. 60.33e(b) undergo an initial
equipment inspection that is at least as protective as the following
within 1 year following approval of the State plan:
(1) At a minimum, an inspection shall include the following:
(i) Inspect all burners, pilot assemblies, and pilot sensing devices
for proper operation; clean pilot flame sensor, as necessary;
(ii) Ensure proper adjustment of primary and secondary chamber
combustion air, and adjust as necessary;
(iii) Inspect hinges and door latches, and lubricate as necessary;
(iv) Inspect dampers, fans, and blowers for proper operation;
(v) Inspect HMIWI door and door gaskets for proper sealing;
(vi) Inspect motors for proper operation;
[[Page 85]]
(vii) Inspect primary chamber refractory lining; clean and repair/
replace lining as necessary;
(viii) Inspect incinerator shell for corrosion and/or hot spots;
(ix) Inspect secondary/tertiary chamber and stack, clean as
necessary;
(x) Inspect mechanical loader, including limit switches, for proper
operation, if applicable;
(xi) Visually inspect waste bed (grates), and repair/seal, as
appropriate;
(xii) For the burn cycle that follows the inspection, document that
the incinerator is operating properly and make any necessary
adjustments;
(xiii) Inspect air pollution control device(s) for proper operation,
if applicable;
(xiv) Inspect waste heat boiler systems to ensure proper operation,
if applicable;
(xv) Inspect bypass stack components;
(xvi) Ensure proper calibration of thermocouples, sorbent feed
systems and any other monitoring equipment; and
(xvii) Generally observe that the equipment is maintained in good
operating condition.
(2) Within 10 operating days following an equipment inspection all
necessary repairs shall be completed unless the owner or operator
obtains written approval from the State agency establishing a date
whereby all necessary repairs of the designated facility shall be
completed.
(b) For approval, a State plan shall require that each small HMIWI
subject to the emission limits under Sec. 60.33e(b) undergo an equipment
inspection annually (no more than 12 months following the previous
annual equipment inspection), as outlined in paragraphs (a)(1) and
(a)(2) of this section.
Sec. 60.37e Compliance, performance testing, and monitoring guidelines.
(a) Except as provided in paragraph (b) of this section, for
approval, a State plan shall include the requirements for compliance and
performance testing listed in Sec. 60.56c of subpart Ec of this part,
excluding the fugitive emissions testing requirements under
Sec. 60.56c(b)(12) and (c)(3).
(b) For approval, a State plan shall require any small HMIWI subject
to the emission limits under Sec. 60.33e(b) to meet the following
compliance and performance testing requirements:
(1) Conduct the performance testing requirements in Sec. 60.56c(a),
(b)(1) through (b)(9), (b)(11) (Hg only), and (c)(1) of subpart Ec of
this part. The 2,000 lb/week limitation under Sec. 60.33e(b) does not
apply during performance tests.
(2) Establish maximum charge rate and minimum secondary chamber
temperature as site-specific operating parameters during the initial
performance test to determine compliance with applicable emission
limits.
(3) Following the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, ensure that the designated facility does not operate above
the maximum charge rate or below the minimum secondary chamber
temperature measured as 3-hour rolling averages (calculated each hour as
the average of the previous 3 operating hours) at all times except
during periods of startup, shutdown and malfunction. Operating parameter
limits do not apply during performance tests. Operation above the
maximum charge rate or below the minimum secondary chamber temperature
shall constitute a violation of the established operating parameter(s).
(4) Except as provided in paragraph (b)(5) of this section,
operation of the designated facility above the maximum charge rate and
below the minimum secondary chamber temperature (each measured on a 3-
hour rolling average) simultaneously shall constitute a violation of the
PM, CO, and dioxin/furan emission limits.
(5) The owner or operator of a designated facility may conduct a
repeat performance test within 30 days of violation of applicable
operating parameter(s) to demonstrate that the designated facility is
not in violation of the applicable emission limit(s). Repeat performance
tests conducted pursuant to this paragraph must be conducted using the
identical operating parameters that indicated a violation under
paragraph (b)(4) of this section.
[[Page 86]]
(c) For approval, a State plan shall include the requirements for
monitoring listed in Sec. 60.57c of subpart Ec of this part, except as
provided for under paragraph (d) of this section.
(d) For approval, a State plan shall include requirements for any
small HMIWI subject to the emission limits under Sec. 60.33e(b) to meet
the following monitoring requirements:
(1) Install, calibrate (to manufacturers' specifications), maintain,
and operate a device for measuring and recording the temperature of the
secondary chamber on a continuous basis, the output of which shall be
recorded, at a minimum, once every minute throughout operation.
(2) Install, calibrate (to manufacturers' specifications), maintain,
and operate a device which automatically measures and records the date,
time, and weight of each charge fed into the HMIWI.
(3) The owner or operator of a designated facility shall obtain
monitoring data at all times during HMIWI operation except during
periods of monitoring equipment malfunction, calibration, or repair. At
a minimum, valid monitoring data shall be obtained for 75 percent of the
operating hours per day and for 90 percent of the operating hours per
calendar quarter that the designated facility is combusting hospital
waste and/or medical/infectious waste.
Sec. 60.38e Reporting and recordkeeping guidelines.
(a) For approval, a State plan shall include the reporting and
recordkeeping requirements listed in Sec. 60.58c(b), (c), (d), (e), and
(f) of subpart Ec of this part, excluding Sec. 60.58c(b)(2)(ii)
(fugitive emissions) and (b)(7) (siting).
(b) For approval, a State plan shall require the owner or operator
of each small HMIWI subject to the emission limits under Sec. 60.33e(b)
to:
(1) Maintain records of the annual equipment inspections, any
required maintenance, and any repairs not completed within 10 days of an
inspection or the timeframe established by the State regulatory agency;
and
(2) Submit an annual report containing information recorded under
paragraph (b)(1) of this section no later than 60 days following the
year in which data were collected. Subsequent reports shall be sent no
later than 12 calendar months following the previous report (once the
unit is subject to permitting requirements under Title V of the Act, the
owner or operator must submit these reports semiannually). The report
shall be signed by the facilities manager.
Sec. 60.39e Compliance times.
(a) Not later than September 15, 1998, each State in which a
designated facility is operating shall submit to the Administrator a
plan to implement and enforce the emission guidelines.
(b) Except as provided in paragraphs (c) and (d) of this section,
State plans shall provide that designated facilities comply with all
requirements of the State plan on or before the date 1 year after EPA
approval of the State plan, regardless of whether a designated facility
is identified in the State plan inventory required by Sec. 60.25(a) of
subpart B of this part.
(c) State plans that specify measurable and enforceable incremental
steps of progress towards compliance for designated facilities planning
to install the necessary air pollution control equipment may allow
compliance on or before the date 3 years after EPA approval of the State
plan (but not later than the September 16, 2002. Suggested measurable
and enforceable activities to be included in State plans are:
(1) Date for submitting a petition for site specific operating
parameters under Sec. 60.56c(i) of subpart Ec of this part.
(2) Date for obtaining services of an architectural and engineering
firm regarding the air pollution control device(s);
(3) Date for obtaining design drawings of the air pollution control
device(s);
(4) Date for ordering the air pollution control device(s);
(5) Date for obtaining the major components of the air pollution
control device(s);
(6) Date for initiation of site preparation for installation of the
air pollution control device(s);
[[Page 87]]
(7) Date for initiation of installation of the air pollution control
device(s);
(8) Date for initial startup of the air pollution control device(s);
and
(9) Date for initial compliance test(s) of the air pollution control
device(s).
(d) State plans that include provisions allowing designated
facilities to petition the State for extensions beyond the compliance
times required in paragraph (b) of this section shall:
(1) Require that the designated facility requesting an extension
submit the following information in time to allow the State adequate
time to grant or deny the extension within 1 year after EPA approval of
the State plan:
(i) Documentation of the analyses undertaken to support the need for
an extension, including an explanation of why up to 3 years after EPA
approval of the State plan is sufficient time to comply with the State
plan while 1 year after EPA approval of the State plan is not
sufficient. The documentation shall also include an evaluation of the
option to transport the waste offsite to a commercial medical waste
treatment and disposal facility on a temporary or permanent basis; and
(ii) Documentation of measurable and enforceable incremental steps
of progress to be taken towards compliance with the emission guidelines.
(2) Include procedures for granting or denying the extension; and
(3) If an extension is granted, require compliance with the emission
guidelines on or before the date 3 years after EPA approval of the State
plan (but not later than September 16, 2002.
(e) For approval, a State plan shall require compliance with
Sec. 60.34e--Operator training and qualification guidelines and
Sec. 60.36e--Inspection guidelines by the date 1 year after EPA approval
of a State plan.
(f) The Administrator shall develop, implement, and enforce a plan
for existing HMIWI located in any State that has not submitted an
approvable plan within date 2 years after September 15, 1997. Such plans
shall ensure that each designated facility is in compliance with the
provisions of this subpart no later than date 5 years after September
15, 1997.
[[Page 88]]
Table 1 to Subpart Ce--Emission Limits for Small, Medium, and Large HMIWI
--------------------------------------------------------------------------------------------------------------------------------------------------------
Emission limits
-------------------------------------------------------------------------------------
Pollutant Units (7 percent oxygen, dry HMIWI size
basis) -------------------------------------------------------------------------------------
Small Medium Large
--------------------------------------------------------------------------------------------------------------------------------------------------------
Particulate matter.................. Milligrams per dry standard 115 (0.05)............. 69 (0.03)............. 34 (0.015).
cubic meter (grains per dry
standard cubic foot).
Carbon monoxide..................... Parts per million by volume. 40..................... 40.................... 40.
Dioxins/furans...................... Nanograms per dry standard 125 (55) or 2.3 (1.0).. 125 (55) or 2.3 (1.0). 125 (55) or 2.3 (1.0).
cubic meter total dioxins/
furans (grains per billion
dry standard cubic feet) or
nanograms per dry standard
cubic meter TEQ (grains per
billion dry standard cubic
feet).
Hydrogen chloride................... Parts per million by volume 100 or 93%............. 100 or 93%............ 100 or 93%.
or percent reduction.
Sulfur dioxide...................... Parts per million by volume. 55..................... 55.................... 55.
Nitrogen oxides..................... Parts per million by volume. 250.................... 250................... 250.
Lead................................ Milligrams per dry standard 1.2 (0.52) or 70%...... 1.2 (0.52) or 70%..... 1.2 (0.52) or 70%.
cubic meter (grains per
thousand dry standard cubic
feet) or percent reduction.
Cadmium............................. Milligrams per dry standard 0.16 (0.07) or 65%..... 0.16 (0.07) or 65%....
cubic meter (grains per
thousand dry standard cubic
feet) or percent reduction.
Mercury............................. Milligrams per dry standard 0.55 (0.24) or 85%..... 0.55 (0.24) or 85%.... 0.55 (0.24) or 85%.
cubic meter (grains per
thousand dry standard cubic
feet) or percent reduction.
--------------------------------------------------------------------------------------------------------------------------------------------------------
[[Page 89]]
Table 2 to Subpart Ce--Emissions Limits for Small HMIWI Which Meet the
Criteria Under Sec. 60.33e(b)
------------------------------------------------------------------------
Units (7 percent HMIWI emission
Pollutant oxygen, dry basis) limits
------------------------------------------------------------------------
Particulate matter............ Milligrams per dry 197 (0.086).
standard cubic meter
(grains per dry
standard cubic foot).
Carbon monoxide............... Parts per million by 40.
volume.
Dioxins/furans................ nanograms per dry 800 (350) or 15
standard cubic meter (6.6).
total dioxins/furans
(grains per billion
dry standard cubic
feet) or nanograms
per dry standard
cubic meter TEQ
(grains per billion
dry standard cubic
feet).
Hydrogen chloride............. Parts per million by 3100.
volume.
Sulfur dioxide................ Parts per million by 55.
volume.
Nitrogen oxides............... Parts per million by 250.
volume.
Lead.......................... Milligrams per dry 10 (4.4).
standard cubic meter
(grains per thousand
dry standard cubic
feet).
Cadmium....................... Milligrams per dry 4 (1.7).
standard cubic meter
(grains per thousand
dry standard cubic
feet).
Mercury....................... Milligrams per dry 7.5 (3.3).
standard cubic meter
(grains per
thousands dry
standard cubic feet).
------------------------------------------------------------------------
Subpart D--Standards of Performance for Fossil-Fuel-Fired Steam
Generators for Which Construction is Commenced After August 17, 1971
Sec. 60.40 Applicability and designation of affected facility.
(a) The affected facilities to which the provisions of this subpart
apply are:
(1) Each fossil-fuel-fired steam generating unit of more than 73
megawatts heat input rate (250 million Btu per hour).
(2) Each fossil-fuel and wood-residue-fired steam generating unit
capable of firing fossil fuel at a heat input rate of more than 73
megawatts (250 million Btu per hour).
(b) Any change to an existing fossil-fuel-fired steam generating
unit to accommodate the use of combustible materials, other than fossil
fuels as defined in this subpart, shall not bring that unit under the
applicability of this subpart.
(c) Except as provided in paragraph (d) of this section, any
facility under paragraph (a) of this section that commenced construction
or modification after August 17, 1971, is subject to the requirements of
this subpart.
(d) The requirements of Secs. 60.44 (a)(4), (a)(5), (b) and (d), and
60.45(f)(4)(vi) are applicable to lignite-fired steam generating units
that commenced construction or modification after December 22, 1976.
(e) Any facility covered under subpart Da is not covered under this
subpart.
[42 FR 37936, July 25, 1977, as amended at 43 FR 9278, Mar. 7, 1978; 44
FR 33612, June 17, 1979]
Sec. 60.41 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act, and in subpart A of this part.
(a) Fossil-fuel fired steam generating unit means a furnace or
boiler used in the process of burning fossil fuel for the purpose of
producing steam by heat transfer.
(b) Fossil fuel means natural gas, petroleum, coal, and any form of
solid, liquid, or gaseous fuel derived from such materials for the
purpose of creating useful heat.
(c) Coal refuse means waste-products of coal mining, cleaning, and
coal preparation operations (e.g. culm, gob, etc.) containing coal,
matrix material, clay, and other organic and inorganic material.
(d) Fossil fuel and wood residue-fired steam generating unit means a
furnace or boiler used in the process of burning fossil fuel and wood
residue for the purpose of producing steam by heat transfer.
(e) Wood residue means bark, sawdust, slabs, chips, shavings, mill
trim, and other wood products derived from wood processing and forest
management operations.
[[Page 90]]
(f) Coal means all solid fuels classified as anthracite, bituminous,
subbituminous, or lignite by ASTM D388-77, 90, 91, 95, or 98a
(incorporated by reference--see Sec. 60.17).
[39 FR 20791, June 14, 1974, as amended at 40 FR 2803, Jan. 16, 1975; 41
FR 51398, Nov. 22, 1976; 43 FR 9278, Mar. 7, 1978; 48 FR 3736, Jan. 27,
1983; 65 FR 61752, Oct. 17, 2000]
Sec. 60.42 Standard for particulate matter.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which:
(1) Contain particulate matter in excess of 43 nanograms per joule
heat input (0.10 lb per million Btu) derived from fossil fuel or fossil
fuel and wood residue.
(2) Exhibit greater than 20 percent opacity except for one six-
minute period per hour of not more than 27 percent opacity.
(b)(1) On or after December 28, 1979, no owner or operator shall
cause to be discharged into the atmosphere from the Southwestern Public
Service Company's Harrington Station 1, in Amarillo, TX, any gases
which exhibit greater than 35 percent opacity, except that a maximum or
42 percent opacity shall be permitted for not more than 6 minutes in any
hour.
(2) Interstate Power Company shall not cause to be discharged into
the atmosphere from its Lansing Station Unit No. 4 in Lansing, IA, any
gases which exhibit greater than 32 percent opacity, except that a
maximum of 39 percent opacity shall be permitted for not more than six
minutes in any hour.
[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976;
42 FR 61537, Dec. 5, 1977; 44 FR 76787, Dec. 28, 1979; 45 FR 36077, May
29, 1980; 45 FR 47146, July 14, 1980; 46 FR 57498, Nov. 24, 1981; 61 FR
49976, Sept. 24, 1996; 65 FR 61752, Oct. 17, 2000]
Sec. 60.43 Standard for sulfur dioxide.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which contain sulfur
dioxide in excess of:
(1) 340 nanograms per joule heat input (0.80 lb per million Btu)
derived from liquid fossil fuel or liquid fossil fuel and wood residue.
(2) 520 nanograms per joule heat input (1.2 lb per million Btu)
derived from solid fossil fuel or solid fossil fuel and wood residue,
except as provided in paragraph (e) of this section.
(b) When different fossil fuels are burned simultaneously in any
combination, the applicable standard (in ng/J) shall be determined by
proration using the following formula:
PSSO2=[y(340) +z(520)]/(y+z)
where:
PSSO2 is the prorated standard for sulfur dioxide when
burning different fuels simultaneously, in nanograms per joule heat
input derived from all fossil fuels fired or from all fossil fuels and
wood residue fired,
y is the percentage of total heat input derived from liquid fossil
fuel, and
z is the percentage of total heat input derived from solid fossil
fuel.
(c) Compliance shall be based on the total heat input from all
fossil fuels burned, including gaseous fuels.
(d) [Reserved]
(e) Units 1 and 2 (as defined in appendix G) at the Newton Power
Station owned or operated by the Central Illinois Public Service Company
will be in compliance with paragraph (a)(2) of this section if Unit 1
and Unit 2 individually comply with paragraph (a)(2) of this section or
if the combined emission rate from Units 1 and 2 does not exceed 470
nanograms per joule (1.1 lb per million Btu) combined heat input to
Units 1 and 2.
[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976;
52 FR 28954, Aug. 4, 1987]
Sec. 60.44 Standard for nitrogen oxides.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which contain nitrogen
oxides, expressed as NO2 in excess of:
[[Page 91]]
(1) 86 nanograms per joule heat input (0.20 lb per million Btu)
derived from gaseous fossil fuel.
(2) 129 nanograms per joule heat input (0.30 lb per million Btu)
derived from liquid fossil fuel, liquid fossil fuel and wood residue, or
gaseous fossil fuel and wood residue.
(3) 300 nanograms per joule heat input (0.70 lb per million Btu)
derived from solid fossil fuel or solid fossil fuel and wood residue
(except lignite or a solid fossil fuel containing 25 percent, by weight,
or more of coal refuse).
(4) 260 nanograms per joule heat input (0.60 lb per million Btu)
derived from lignite or lignite and wood residue (except as provided
under paragraph (a)(5) of this section).
(5) 340 nanograms per joule heat input (0.80 lb per million Btu)
derived from lignite which is mined in North Dakota, South Dakota, or
Montana and which is burned in a cyclone-fired unit.
(b) Except as provided under paragraphs (c) and (d) of this section,
when different fossil fuels are burned simultaneously in any
combination, the applicable standard (in ng/J) is determined by
proration using the following formula:
[GRAPHIC] [TIFF OMITTED] TC16NO91.000
where:
PSNOx=is the prorated standard for nitrogen oxides when
burning different fuels simultaneously, in nanograms per joule
heat input derived from all fossil fuels fired or from all
fossil fuels and wood residue fired;
w= is the percentage of total heat input derived from lignite;
x= is the percentage of total heat input derived from gaseous fossil
fuel;
y= is the percentage of total heat input derived from liquid fossil
fuel; and
z= is the percentage of total heat input derived from solid fossil fuel
(except lignite).
(c) When a fossil fuel containing at least 25 percent, by weight, of
coal refuse is burned in combination with gaseous, liquid, or other
solid fossil fuel or wood residue, the standard for nitrogen oxides does
not apply.
(d) Cyclone-fired units which burn fuels containing at least 25
percent of lignite that is mined in North Dakota, South Dakota, or
Montana remain subject to paragraph (a)(5) of this section regardless of
the types of fuel combusted in combination with that lignite.
[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976;
43 FR 9278, Mar. 7, 1978; 51 FR 42797, Nov. 25, 1986]
Sec. 60.45 Emission and fuel monitoring.
(a) Each owner or operator shall install, calibrate, maintain, and
operate continuous monitoring systems for measuring the opacity of
emissions, sulfur dioxide emissions, nitrogen oxides emissions, and
either oxygen or carbon dioxide except as provided in paragraph (b) of
this section.
(b) Certain of the continuous monitoring system requirements under
paragraph (a) of this section do not apply to owners or operators under
the following conditions:
(1) For a fossil fuel-fired steam generator that burns only gaseous
fossil fuel, continuous monitoring systems for measuring the opacity of
emissions and sulfur dioxide emissions are not required.
(2) For a fossil fuel-fired steam generator that does not use a flue
gas desulfurization device, a continuous monitoring system for measuring
sulfur dioxide emissions is not required if the owner or operator
monitors sulfur dioxide emissions by fuel sampling and analysis.
(3) Notwithstanding Sec. 60.13(b), installation of a continuous
monitoring system for nitrogen oxides may be delayed until after the
initial performance tests under Sec. 60.8 have been conducted. If the
owner or operator demonstrates during the performance test that
emissions of nitrogen oxides are less than 70 percent of the applicable
standards in Sec. 60.44, a continuous monitoring system for measuring
nitrogen oxides emissions is not required. If the initial performance
test results show that nitrogen oxide emissions are greater than 70
percent of the applicable standard, the owner or operator shall install
a continuous monitoring system for nitrogen oxides within one year after
the date of the initial performance tests under Sec. 60.8 and comply
with all other applicable monitoring requirements under this part.
[[Page 92]]
(4) If an owner or operator does not install any continuous
monitoring systems for sulfur oxides and nitrogen oxides, as provided
under paragraphs (b)(1) and (b)(3) or paragraphs (b)(2) and (b)(3) of
this section a continuous monitoring system for measuring either oxygen
or carbon dioxide is not required.
(c) For performance evaluations under Sec. 60.13(c) and calibration
checks under Sec. 60.13(d), the following procedures shall be used:
(1) Methods 6, 7, and 3B, as applicable, shall be used for the
performance evaluations of sulfur dioxide and nitrogen oxides continuous
monitoring systems. Acceptable alternative methods for Methods 6, 7, and
3B are given in Sec. 60.46(d).
(2) Sulfur dioxide or nitric oxide, as applicable, shall be used for
preparing calibration gas mixtures under Performance Specification 2 of
appendix B to this part.
(3) For affected facilities burning fossil fuel(s), the span value
for a continuous monitoring system measuring the opacity of emissions
shall be 80, 90, or 100 percent and for a continuous monitoring system
measuring sulfur oxides or nitrogen oxides the span value shall be
determined as follows:
[In parts per million]
------------------------------------------------------------------------
Span value for Span value for
Fossil fuel sulfur dioxide nitrogen oxides
------------------------------------------------------------------------
Gas............................... (\1\ ) 500
Liquid............................ 1,000 500
Solid............................. 1,500 1000
Combinations...................... 1,000y+1,500z 500(x+y)+1,000z
------------------------------------------------------------------------
\1\ Not applicable.
where:
x=the fraction of total heat input derived from gaseous fossil fuel, and
y=the fraction of total heat input derived from liquid fossil fuel, and
z=the fraction of total heat input derived from solid fossil fuel.
(4) All span values computed under paragraph (c)(3) of this section
for burning combinations of fossil fuels shall be rounded to the nearest
500 ppm.
(5) For a fossil fuel-fired steam generator that simultaneously
burns fossil fuel and nonfossil fuel, the span value of all continuous
monitoring systems shall be subject to the Administrator's approval.
(d) [Reserved]
(e) For any continuous monitoring system installed under paragraph
(a) of this section, the following conversion procedures shall be used
to convert the continuous monitoring data into units of the applicable
standards (ng/J, lb/million Btu):
(1) When a continuous monitoring system for measuring oxygen is
selected, the measurement of the pollutant concentration and oxygen
concentration shall each be on a consistent basis (wet or dry).
Alternative procedures approved by the Administrator shall be used when
measurements are on a wet basis. When measurements are on a dry basis,
the following conversion procedure shall be used:
E=CF[20.9/(20.9--percent O2)]
where:
E, C, F, and %O2 are determined under paragraph (f) of this
section.
(2) When a continuous monitoring system for measuring carbon dioxide
is selected, the measurement of the pollutant concentration and carbon
dioxide concentration shall each be on a consistent basis (wet or dry)
and the following conversion procedure shall be used:
E=CFc [100/percent CO2]
where:
E, C, Fc and %CO2 are determined under paragraph
(f) of this section.
(f) The values used in the equations under paragraphs (e) (1) and
(2) of this section are derived as follows:
(1) E=pollutant emissions, ng/J (lb/million Btu).
(2) C=pollutant concentration, ng/dscm (lb/dscf), determined by
multiplying the average concentration (ppm) for each one-hour period by
4.15 x 10 4 M ng/dscm per ppm (2.59 x 10- 9 M lb/
dscf per ppm) where M=pollutant molecular weight, g/g-mole (lb/lb-mole).
M=64.07 for sulfur dioxide and 46.01 for nitrogen oxides.
(3) %O2, %CO2=oxygen or carbon dioxide volume
(expressed as percent), determined with equipment specified under
paragraph (a) of this section.
(4) F, Fc=a factor representing a ratio of the volume of
dry flue gases generated to the calorific value of the fuel combusted
(F), and a factor representing a ratio of the volume of carbon dioxide
generated to the calorific
[[Page 93]]
value of the fuel combusted (Fc), respectively. Values of F
and Fc are given as follows:
(i) For anthracite coal as classified according to ASTM D388-77, 90,
91, 95, or 98a (incorporated by reference--see Sec. 60.17),
F=2,723 x 10-\17\ dscm/J (10,140 dscf/million Btu and
Fc=0.532 x 10 -\17\ scm CO2/J (1,980
scf CO2/million Btu).
(ii) For subbituminous and bituminous coal as classified according
to ASTM D388-77, 90, 91, 95, or 98a (incorporated by reference--see
Sec. 60.17), F=2.637 x 10 -\7\ dscm/J (9,820 dscf/million
Btu) and Fc=0.486 x 10-\7\ scm CO2/J
(1,810 scf CO2/million Btu).
(iii) For liquid fossil fuels including crude, residual, and
distillate oils, F=2.476 x 10-7 dscm/J (9,220 dscf/million
Btu) and Fc=0.384 x 10-7 scm CO2/J
(1,430 scf CO2/million Btu).
(iv) For gaseous fossil fuels, F=2.347 x 10- 7 dscm/J
(8,740 dscf/million Btu). For natural gas, propane, and butane fuels,
Fc=0.279 x 10- 7 scm CO2/J (1,040 scf
CO2/million Btu) for natural gas, 0.322 x 10- 7
scm CO2/J (1,200 scf CO2/million Btu) for propane,
and 0.338 x 10- 7 scm CO2/J (1,260 scf
CO2/million Btu) for butane.
(v) For bark F=2.589 x 10-7 dscm/J (9,640 dscf/million
Btu) and Fc=0.500 x 10-7 scm CO2/J
(1,840 scf CO!2/ million Btu). For wood residue other than
bark F=2.492 x 10-7 dscm/J (9,280 dscf/million Btu) and
Fc=0.494 x 10-7 scm CO2/J (1,860 scf CO
!2/ million Btu).
(vi) For lignite coal as classified according to ASTM D388-77, 90,
91, 95, or 98a (incorporated by reference--see Sec. 60.17),
F=2.659 x 10-\7\ dscm/J (9,900 dscf/million Btu) and
Fc=0.516 x 10 -\7\ scm CO2/J (1,920 scf
CO2/million Btu).
(5) The owner or operator may use the following equation to
determine an F factor (dscm/J or dscf/million Btu) on a dry basis (if it
is desired to calculate F on a wet basis, consult the Administrator) or
Fc factor (scm CO2/J, or scf CO2/
million Btu) on either basis in lieu of the F or Fc factors
specified in paragraph (f)(4) of this section:
[GRAPHIC] [TIFF OMITTED] TC16NO91.001
(i) H, C, S, N, and O are content by weight of hydrogen, carbon,
sulfur, nitrogen, and oxygen (expressed as percent), respectively, as
determined on the same basis as GCV by ultimate analysis of the fuel
fired, using ASTM D3178-73 (Reapproved 1979), 89, or D3176-74 or 89
(solid fuels) or computed from results using ASTM D1137-53 or 75, D1945-
64, 76, 91, or 96 or D1946-77 or 90 (Reapproved 1994) (gaseous fuels) as
applicable. (These five methods are incorporated by reference--see
Sec. 60.17.)
(ii) GVC is the gross calorific value (kJ/kg, Btu/lb) of the fuel
combusted determined by the ASTM test methods D2015-77 for solid fuels
and D1826-77 for gaseous fuels as applicable. (These two methods are
incorporated by reference--see Sec. 60.17.)
(iii) For affected facilities which fire both fossil fuels and
nonfossil fuels, the
[[Page 94]]
F or Fc value shall be subject to the Administrator's
approval.
(6) For affected facilities firing combinations of fossil fuels or
fossil fuels and wood residue, the F or Fc factors determined
by paragraphs (f)(4) or (f)(5) of this section shall be prorated in
accordance with the applicable formula as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.002
where:
Xi=the fraction of total heat input derived from each type of
fuel (e.g. natural gas, bituminous coal, wood residue, etc.)
Fi or (Fc)i=the applicable F or Fc
factor for each fuel type determined in accordance with
paragraphs (f)(4) and (f)(5) of this section.
n=the number of fuels being burned in combination.
(g) Excess emission and monitoring system performance reports shall
be submitted to the Administrator semiannually for each six-month period
in the calendar year. All semiannual reports shall be postmarked by the
30th day following the end of each six-month period. Each excess
emission and MSP report shall include the information required in
Sec. 60.7(c). Periods of excess emissions and monitoring systems (MS)
downtime that shall be reported are defined as follows:
(1) Opacity. Excess emissions are defined as any six-minute period
during which the average opacity of emissions exceeds 20 percent
opacity, except that one six-minute average per hour of up to 27 percent
opacity need not be reported.
(i) For sources subject to the opacity standard of Sec. 60.42(b)(1),
excess emissions are defined as any six-minute period during which the
average opacity of emissions exceeds 35 percent opacity, except that one
six-minute average per hour of up to 42 percent opacity need not be
reported.
(ii) For sources subject to the opacity standard of
Sec. 60.42(b)(2), excess emissions are defined as any six-minute period
during which the average opacity of emissions exceeds 32 percent
opacity, except that one six-minute average per hour of up to 39 percent
opacity need not be reported.
(2) Sulfur dioxide. Excess emissions for affected facilities are
defined as:
(i) Any three-hour period during which the average emissions
(arithmetic average of three contiguous one-hour periods) of sulfur
dioxide as measured by a continuous monitoring system exceed the
applicable standard under Sec. 60.43.
(3) Nitrogen oxides. Excess emissions for affected facilities using
a continuous monitoring system for measuring nitrogen oxides are defined
as any three-hour period during which the average emissions (arithmetic
average of three contiguous one-hour periods) exceed the applicable
standards under Sec. 60.44.
[40 FR 46256, Oct. 6, 1975]
Editorial Note 1: For Federal Register citations affecting
Sec. 60.45, see the List of CFR Sections Affected, which appears in the
Finding Aids section of the printed volume and on GPO Access.
Editorial Note 2: At 65 FR 61752, Oct. 17, 2000,
Sec. 60.45(f)(5)(ii) was amended by revising the words ``ASTM D1826-77''
to read ``ASTM D1826-77 or 94.'' and by revising the words ``ASTM D2015-
77'' to read ``ASTM D2015-77 (Reapproved 1978), 96, or D5865-98.''
However, this amendment could not be incorporated because these words do
not exist in paragraph (f)(5)(ii).
Sec. 60.46 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
Acceptable alternative methods and procedures are given in paragraph (d)
of this section.
(b) The owner or operator shall determine compliance with the
particulate matter, SO2, and NOx standards in
Secs. 60.42, 60.43, and 60.44 as follows:
(1) The emission rate (E) of particulate matter, SO2, or
NOx shall be computed for each run using the following
equation:
E=C Fd (20.9)/(20.9-% 02)
E = emission rate of pollutant, ng/J (1b/million Btu).
C = concentration of pollutant, ng/dscm (1b/dscf).
%O2 = oxygen concentration, percent dry basis.
[[Page 95]]
Fd = factor as determined from Method 19.
(2) Method 5 shall be used to determine the particular matter
concentration (C) at affected facilities without wet flue-gas-
desulfurization (FGD) systems and Method 5B shall be used to determine
the particulate matter concentration (C) after FGD systems.
(i) The sampling time and sample volume for each run shall be at
least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder
heating systems in the sampling train shall be set to provide an average
gas temperature of 16014 deg.C (32025 deg.F).
(ii) The emission rate correction factor, integrated or grab
sampling and analysis procedure of Method 3B shall be used to determine
the O2 concentration (%O2). The O2
sample shall be obtained simultaneously with, and at the same traverse
points as, the particulate sample. If the grab sampling procedure is
used, the O2 concentration for the run shall be the
arithmetic mean of the sample O2 concentrations at all
traverse points.
(iii) If the particulate run has more than 12 traverse points, the
O2 traverse points may be reduced to 12 provided that Method
1 is used to locate the 12 O2 traverse points.
(3) Method 9 and the procedures in Sec. 60.11 shall be used to
determine opacity.
(4) Method 6 shall be used to determine the SO2
concentration.
(i) The sampling site shall be the same as that selected for the
particulate sample. The sampling location in the duct shall be at the
centroid of the cross section or at a point no closer to the walls than
1 m (3.28 ft). The sampling time and sample volume for each sample run
shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two samples
shall be taken during a 1-hour period, with each sample taken within a
30-minute interval.
(ii) The emission rate correction factor, integrated sampling and
analysis procedure of Method 3B shall be used to determine the
O2 concentration (%O2). The O2 sample
shall be taken simultaneously with, and at the same point as, the
SO2 sample. The SO2 emission rate shall be
computed for each pair of SO2 and O2 samples. The
SO2 emission rate (E) for each run shall be the arithmetic
mean of the results of the two pairs of samples.
(5) Method 7 shall be used to determine the NOx
concentration.
(i) The sampling site and location shall be the same as for the
SO2 sample. Each run shall consist of four grab samples, with
each sample taken at about 15-minute intervals.
(ii) For each NOx sample, the emission rate correction
factor, grab sampling and analysis procedure of Method 3B shall be used
to determine the O2 concentration (%O2). The
sample shall be taken simultaneously with, and at the same point as, the
NOx sample.
(iii) The NOx emission rate shall be computed for each
pair of NOx and O2 samples. The NOx
emission rate (E) for each run shall be the arithmetic mean of the
results of the four pairs of samples.
(c) When combinations of fossil fuels or fossil fuel and wood
residue are fired, the owner or operator (in order to compute the
prorated standard as shown in Secs. 60.43(b) and 60.44(b)) shall
determine the percentage (w, x, y, or z) of the total heat input derived
from each type of fuel as follows:
(1) The heat input rate of each fuel shall be determined by
multiplying the gross calorific value of each fuel fired by the rate of
each fuel burned.
(2) ASTM Methods D2015-77 (Reapproved 1978), 96, or D5865-98 (solid
fuels), D240-76 or 92 (liquid fuels), or D1826-77 or 94 (gaseous fuels)
(incorporated by reference--see Sec. 60.17) shall be used to determine
the gross calorific values of the fuels. The method used to determine
the calorific value of wood residue must be approved by the
Administrator.
(3) Suitable methods shall be used to determine the rate of each
fuel burned during each test period, and a material balance over the
steam generating system shall be used to confirm the rate.
(d) The owner or operator may use the following as alternatives to
the reference methods and procedures in this section or in other
sections as specified:
(1) The emission rate (E) of particulate matter, SO2 and
NOx may be determined by using the Fc factor,
provided that the following procedure is used:
[[Page 96]]
(i) The emission rate (E) shall be computed using the following
equation:
E=C Fc (100/%CO2)
where:
E=emission rate of pollutant, ng/J (lb/million Btu).
C=concentration of pollutant, ng/dscm (lb/dscf).
%CO2=carbon dioxide concentration, percent dry basis.
Fc=factor as determined in appropriate sections of Method 19.
(ii) If and only if the average Fc factor in Method 19 is
used to calculate E and either E is from 0.97 to 1.00 of the emission
standard or the relative accuracy of a continuous emission monitoring
system is from 17 to 20 percent, then three runs of Method 3B shall be
used to determine the O2 and CO2 concentration
according to the procedures in paragraph (b) (2)(ii), (4)(ii), or
(5)(ii) of this section. Then if Fo (average of three runs),
as calculated from the equation in Method 3B, is more than 3
percent than the average Fo value, as determined from the
average values of Fd and Fc in Method 19, i.e.,
Foa=0.209 (Fda/Fca), then the following
procedure shall be followed:
(A) When Fo is less than 0.97 Foa, then E
shall be increased by that proportion under 0.97 Foa, e.g.,
if Fo is 0.95 Foa, E shall be increased by 2
percent. This recalculated value shall be used to determine compliance
with the emission standard.
(B) When Fo is less than 0.97 Foa and when the
average difference (d) between the continuous monitor minus the
reference methods is negative, then E shall be increased by that
proportion under 0.97 Foa, e.g., if Fo is 0.95
Foa, E shall be increased by 2 percent. This recalculated
value shall be used to determine compliance with the relative accuracy
specification.
(C) When Fo is greater than 1.03 Foa and when
the average difference d is positive, then E shall be decreased by that
proportion over 1.03 Foa, e.g., if Fo is 1.05
Foa, E shall be decreased by 2 percent. This recalculated
value shall be used to determine compliance with the relative accuracy
specification.
(2) For Method 5 or 5B, Method 17 may be used at facilities with or
without wet FGD systems if the stack gas temperature at the sampling
location does not exceed an average temperature of 160 deg.C (320
deg.F). The procedures of sections 2.1 and 2.3 of Method 5B may be used
with Method 17 only if it is used after wet FGD systems. Method 17 shall
not be used after wet FGD systems if the effluent gas is saturated or
laden with water droplets.
(3) Particulate matter and SO2 may be determined
simultaneously with the Method 5 train provided that the following
changes are made:
(i) The filter and impinger apparatus in sections 2.1.5 and 2.1.6 of
Method 8 is used in place of the condenser (section 2.1.7) of Method 5.
(ii) All applicable procedures in Method 8 for the determination of
SO2 (including moisture) are used:
(4) For Method 6, Method 6C may be used. Method 6A may also be used
whenever Methods 6 and 3B data are specified to determine the
SO2 emission rate, under the conditions in paragraph (d)(1)
of this section.
(5) For Method 7, Method 7A, 7C, 7D, or 7E may be used. If Method
7C, 7D, or 7E is used, the sampling time for each run shall be at least
1 hour and the integrated sampling approach shall be used to determine
the O2 concentration (%O2) for the emission rate
correction factor.
(6) For Method 3, Method 3A or 3B may be used.
(7) For Method 3B, Method 3A may be used.
[54 FR 6662, Feb. 14, 1989; 54 FR 21344, May 17, 1989, as amended at 55
FR 5212, Feb. 14, 1990; 65 FR 61752, Oct. 17, 2000]
Subpart Da--Standards of Performance for Electric Utility Steam
Generating Units for Which Construction is Commenced After September 18,
1978
Source: 44 FR 33613, June 11, 1979, unless otherwise noted.
Sec. 60.40a Applicability and designation of affected facility.
(a) The affected facility to which this subpart applies is each
electric utility steam generating unit:
(1) That is capable of combusting more than 73 megawatts (250
million
[[Page 97]]
Btu/hour) heat input of fossil fuel (either alone or in combination with
any other fuel); and
(2) For which construction or modification is commenced after
September 18, 1978.
(b) Unless and until subpart GG of this part extends the
applicability of subpart GG of this part to electric utility steam
generators, this subpart applies to electric utility combined cycle gas
turbines that are capable of combusting more than 73 megawatts (250
million Btu/hour) heat input of fossil fuel in the steam generator. Only
emissions resulting from combustion of fuels in the steam generating
unit are subject to this subpart. (The gas turbine emissions are subject
to subpart GG of this part.)
(c) Any change to an existing fossil-fuel-fired steam generating
unit to accommodate the use of combustible materials, other than fossil
fuels, shall not bring that unit under the applicability of this
subpart.
(d) Any change to an existing steam generating unit originally
designed to fire gaseous or liquid fossil fuels, to accommodate the use
of any other fuel (fossil or nonfossil) shall not bring that unit under
the applicability of this subpart.
[44 FR 33613, June 11, 1979, as amended at 63 FR 49453, Sept. 16, 1998]
Sec. 60.41a Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
Anthracite means coal that is classified as anthracite according to
the American Society of Testing and Materials' (ASTM) Standard
Specification for Classification of Coals by Rank D388-77 (incorporated
by reference--see Sec. 60.17).
Available purchase power means the lesser of the following:
(a) The sum of available system capacity in all neighboring
companies.
(b) The sum of the rated capacities of the power interconnection
devices between the principal company and all neighboring companies,
minus the sum of the electric power load on these interconnections.
(c) The rated capacity of the power transmission lines between the
power interconnection devices and the electric generating units (the
unit in the principal company that has the malfunctioning flue gas
desulfurization system and the unit(s) in the neighboring company
supplying replacement electrical power) less the electric power load on
these transmission lines.
Available system capacity means the capacity determined by
subtracting the system load and the system emergency reserves from the
net system capacity.
Boiler operating day means a 24-hour period during which fossil fuel
is combusted in a steam generating unit for the entire 24 hours.
Coal refuse means waste products of coal mining, physical coal
cleaning, and coal preparation operations (e.g. culm, gob, etc.)
containing coal, matrix material, clay, and other organic and inorganic
material.
Combined cycle gas turbine means a stationary turbine combustion
system where heat from the turbine exhaust gases is recovered by a steam
generating unit.
Duct burner means a device that combusts fuel and that is placed in
the exhaust duct from another source, such as a stationary gas turbine,
internal combustion engine, kiln, etc., to allow the firing of
additional fuel to heat the exhaust gases before the exhaust gases enter
a heat recovery steam generating unit.
Electric utility combined cycle gas turbine means any combined cycle
gas turbine used for electric generation that is constructed for the
purpose of supplying more than one-third of its potential electric
output capacity and more than 25 MW electrical output to any utility
power distribution system for sale. Any steam distribution system that
is constructed for the purpose of providing steam to a steam electric
generator that would produce electrical power for sale is also
considered in determining the electrical energy output capacity of the
affected facility.
Electric utility company means the largest interconnected
organization, business, or governmental entity that generates electric
power for sale (e.g., a holding company with operating subsidiary
companies).
[[Page 98]]
Electric utility steam generating unit means any steam electric
generating unit that is constructed for the purpose of supplying more
than one-third of its potential electric output capacity and more than
25 MW electrical output to any utility power distribution system for
sale. Any steam supplied to a steam distribution system for the purpose
of providing steam to a steam-electric generator that would produce
electrical energy for sale is also considered in determining the
electrical energy output capacity of the affected facility.
Emergency condition means that period of time when:
(a) The electric generation output of an affected facility with a
malfunctioning flue gas desulfurization system cannot be reduced or
electrical output must be increased because:
(1) All available system capacity in the principal company
interconnected with the affected facility is being operated, and
(2) All available purchase power interconnected with the affected
facility is being obtained, or
(b) The electric generation demand is being shifted as quickly as
possible from an affected facility with a malfunctioning flue gas
desulfurization system to one or more electrical generating units held
in reserve by the principal company or by a neighboring company, or
(c) An affected facility with a malfunctioning flue gas
desulfurization system becomes the only available unit to maintain a
part or all of the principal company's system emergency reserves and the
unit is operated in spinning reserve at the lowest practical electric
generation load consistent with not causing significant physical damage
to the unit. If the unit is operated at a higher load to meet load
demand, an emergency condition would not exist unless the conditions
under (a) of this definition apply.
Fossil fuel means natural gas, petroleum, coal, and any form of
solid, liquid, or gaseous fuel derived from such material for the
purpose of creating useful heat.
Gross output means the gross useful work performed by the steam
generated. For units generating only electricity, the gross useful work
performed is the gross electrical output from the turbine/generator set.
For cogeneration units, the gross useful work performed is the gross
electrical output plus one half the useful thermal output (i.e., steam
delivered to an industrial process).
24-hour period means the period of time between 12:01 a.m. and 12:00
midnight.
Interconnected means that two or more electric generating units are
electrically tied together by a network of power transmission lines, and
other power transmission equipment.
Lignite means coal that is classified as lignite A or B according to
the American Society of Testing and Materials' (ASTM) Standard
Specification for Classification of Coals by Rank D388-77, 90, 91, 95,
or 98a (incorporated by reference--see Sec. 60.17).
Neighboring company means any one of those electric utility
companies with one or more electric power interconnections to the
principal company and which have geographically adjoining service areas.
Net system capacity means the sum of the net electric generating
capability (not necessarily equal to rated capacity) of all electric
generating equipment owned by an electric utility company (including
steam generating units, internal combustion engines, gas turbines,
nuclear units, hydroelectric units, and all other electric generating
equipment) plus firm contractual purchases that are interconnected to
the affected facility that has the malfunctioning flue gas
desulfurization system. The electric generating capability of equipment
under multiple ownership is prorated based on ownership unless the
proportional entitlement to electric output is otherwise established by
contractual arrangement.
Noncontinental area means the State of Hawaii, the Virgin Islands,
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern
Mariana Islands.
Potential combustion concentration means the theoretical emissions
(ng/J, lb/million Btu heat input) that would result from combustion of a
fuel in an uncleaned state without emission control systems) and:
(a) For particulate matter is:
[[Page 99]]
(1) 3,000 ng/J (7.0 lb/million Btu) heat input for solid fuel; and
(2) 73 ng/J (0.17 lb/million Btu) heat input for liquid fuels.
(b) For sulfur dioxide is determined under Sec. 60.48a(b).
(c) For nitrogen oxides is:
(1) 290 ng/J (0.67 lb/million Btu) heat input for gaseous fuels;
(2) 310 ng/J (0.72 lb/million Btu) heat input for liquid fuels; and
(3) 990 ng/J (2.30 lb/million Btu) heat input for solid fuels.
Potential electrical output capacity is defined as 33 percent of the
maximum design heat input capacity of the steam generating unit (e.g., a
steam generating unit with a 100-MW (340 million Btu/hr) fossil-fuel
heat input capacity would have a 33-MW potential electrical output
capacity). For electric utility combined cycle gas turbines the
potential electrical output capacity is determined on the basis of the
fossil-fuel firing capacity of the steam generator exclusive of the heat
input and electrical power contribution by the gas turbine.
Principal company means the electric utility company or companies
which own the affected facility.
Resource recovery unit means a facility that combusts more than 75
percent non-fossil fuel on a quarterly (calendar) heat input basis.
Solid-derived fuel means any solid, liquid, or gaseous fuel derived
from solid fuel for the purpose of creating useful heat and includes,
but is not limited to, solvent refined coal, liquified coal, and
gasified coal.
Spare flue gas desulfurization system module means a separate system
of sulfur dioxide emission control equipment capable of treating an
amount of flue gas equal to the total amount of flue gas generated by an
affected facility when operated at maximum capacity divided by the total
number of nonspare flue gas desulfurization modules in the system.
Spinning reserve means the sum of the unutilized net generating
capability of all units of the electric utility company that are
synchronized to the power distribution system and that are capable of
immediately accepting additional load. The electric generating
capability of equipment under multiple ownership is prorated based on
ownership unless the proportional entitlement to electric output is
otherwise established by contractual arrangement.
Steam generating unit means any furnace, boiler, or other device
used for combusting fuel for the purpose of producing steam (including
fossil-fuel-fired steam generators associated with combined cycle gas
turbines; nuclear steam generators are not included).
Subbituminous coal means coal that is classified as subbituminous A,
B, or C according to the American Society of Testing and Materials
(ASTM) Standard Specification for Classification of Coals by Rank D388-
77, 90, 91, 95, or 98a (incorporated by reference--see Sec. 60.17).
System emergency reserves means an amount of electric generating
capacity equivalent to the rated capacity of the single largest electric
generating unit in the electric utility company (including steam
generating units, internal combustion engines, gas turbines, nuclear
units, hydroelectric units, and all other electric generating equipment)
which is interconnected with the affected facility that has the
malfunctioning flue gas desulfurization system. The electric generating
capability of equipment under multiple ownership is prorated based on
ownership unless the proportional entitlement to electric output is
otherwise established by contractual arrangement.
System load means the entire electric demand of an electric utility
company's service area interconnected with the affected facility that
has the malfunctioning flue gas desulfurization system plus firm
contractual sales to other electric utility companies. Sales to other
electric utility companies (e.g., emergency power) not on a firm
contractual basis may also be included in the system load when no
available system capacity exists in the electric utility company to
which the power is supplied for sale.
[44 FR 33613, June 11, 1979, as amended at 48 FR 3737, Jan. 27, 1983; 63
FR 49453, Sept. 16, 1998; 65 FR 61752, Oct. 17, 2000; 66 FR 18551, Apr.
10, 2001]
Sec. 60.42a Standard for particulate matter.
(a) On and after the date on which the performance test required to
be
[[Page 100]]
conducted under Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which contain
particulate matter in excess of:
(1) 13 ng/J (0.03 lb/million Btu) heat input derived from the
combustion of solid, liquid, or gaseous fuel;
(2) 1 percent of the potential combustion concentration (99 percent
reduction) when combusting solid fuel; and
(3) 30 percent of potential combustion concentration (70 percent
reduction) when combusting liquid fuel.
(b) On and after the date the particulate matter performance test
required to be conducted under Sec. 60.8 is completed, no owner or
operator subject to the provisions of this subpart shall cause to be
discharged into the atmosphere from any affected facility any gases
which exhibit greater than 20 percent opacity (6-minute average), except
for one 6-minute period per hour of not more than 27 percent opacity.
Sec. 60.43a Standard for sulfur dioxide.
(a) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is completed, no owner or
operator subject to the provisions of this subpart shall cause to be
discharged into the atmosphere from any affected facility which combusts
solid fuel or solid-derived fuel, except as provided under paragraphs
(c), (d), (f) or (h) of this section, any gases which contain sulfur
dioxide in excess of:
(1) 520 ng/J (1.20 lb/million Btu) heat input and 10 percent of the
potential combustion concentration (90 percent reduction), or
(2) 30 percent of the potential combustion concentration (70 percent
reduction), when emissions are less than 260 ng/J (0.60 lb/million Btu)
heat input.
(b) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is completed, no owner or
operator subject to the provisions of this subpart shall cause to be
discharged into the atmosphere from any affected facility which combusts
liquid or gaseous fuels (except for liquid or gaseous fuels derived from
solid fuels and as provided under paragraphs (e) or (h) of this
section), any gases which contain sulfur dioxide in excess of:
(1) 340 ng/J (0.80 lb/million Btu) heat input and 10 percent of the
potential combustion concentration (90 percent reduction), or
(2) 100 percent of the potential combustion concentration (zero
percent reduction) when emissions are less than 86 ng/J (0.20 lb/million
Btu) heat input.
(c) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is complete, no owner or
operator subject to the provisions of this subpart shall cause to be
discharged into the atmosphere from any affected facility which combusts
solid solvent refined coal (SRC-I) any gases which contain sulfur
dioxide in excess of 520 ng/J (1.20 lb/million Btu) heat input and 15
percent of the potential combustion concentration (85 percent reduction)
except as provided under paragraph (f) of this section; compliance with
the emission limitation is determined on a 30-day rolling average basis
and compliance with the percent reduction requirement is determined on a
24-hour basis.
(d) Sulfur dioxide emissions are limited to 520 ng/J (1.20 lb/
million Btu) heat input from any affected facility which:
(1) Combusts 100 percent anthracite,
(2) Is classified as a resource recovery unit, or
(3) Is located in a noncontinental area and combusts solid fuel or
solid-derived fuel.
(e) Sulfur dioxide emissions are limited to 340 ng/J (0.80 lb/
million Btu) heat input from any affected facility which is located in a
noncontinental area and combusts liquid or gaseous fuels (excluding
solid-derived fuels).
(f) The emission reduction requirements under this section do not
apply to any affected facility that is operated under an SO2
commercial demonstration permit issued by the Administrator in
accordance with the provisions of Sec. 60.45a.
(g) Compliance with the emission limitation and percent reduction
requirements under this section are both determined on a 30-day rolling
average basis except as provided under paragraph (c) of this section.
[[Page 101]]
(h) When different fuels are combusted simultaneously, the
applicable standard is determined by proration using the following
formula:
(1) If emissions of sulfur dioxide to the atmosphere are greater
than 260 ng/J (0.60 lb/million Btu) heat input
Es=(340x+520 y)/100 and
%Ps=10
(2) If emissions of sulfur dioxide to the atmosphere are equal to or
less than 260 ng/J (0.60 lb/million Btu) heat input:
Es=(340x+520 y)/100 and
%Ps=(10x+30 y)/100
where:
Es is the prorated sulfur dioxide emission limit (ng/J heat
input),
%Ps is the percentage of potential sulfur dioxide emission
allowed.
x is the percentage of total heat input derived from the combustion of
liquid or gaseous fuels (excluding solid-derived fuels)
y is the percentage of total heat input derived from the combustion of
solid fuel (including solid-derived fuels)
[44 FR 33613, June 11, 1979, as amended at 54 FR 6663, Feb. 14, 1989; 54
FR 21344, May 17, 1989; 65 FR 61752, Oct. 17, 2000]
Sec. 60.44a Standard for nitrogen oxides.
(a) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is completed, no owner or
operator subject to the provisions of this subpart shall cause to be
discharged into the atmosphere from any affected facility, except as
provided under paragraphs (b) and (d) of this section, any gases which
contain nitrogen oxides (expressed as NO2) in excess of the
following emission limits, based on a 30-day rolling average, except as
provided under Sec. 60.46a(j)(1):
(1) NOx emission limits.
------------------------------------------------------------------------
Emission limit for
heat input
-----------------------
Fuel type (lb/
ng/J million
Btu)
------------------------------------------------------------------------
Gaseous fuels:
Coal-derived fuels............................ 210 0.50
All other fuels............................... 86 0.20
Liquid fuels:
Coal-derived fuels............................ 210 0.50
Shale oil..................................... 210 0.50
All other fuels............................... 130 0.30
Solid fuels:
Coal-derived fuels............................ 210 0.50
Any fuel containing more than 25%, by weight, (\1\ ) (\1\ )
coal refuse..................................
Any fuel containing more than 25%, by weight, 340 0.80
lignite if the lignite is mined in North
Dakota, South Dakota, or Montana, and is
combusted in a slag tap furnace\2\...........
Any fuel containing more than 25%, by weight,
lignite not subject to the 340 ng/J heat
input emission limit\2\......................
Subbituminous coal............................ 210 0.50
Bituminous coal............................... 260 0.60
Anthracite coal............................... 260 0.60
All other fuels............................... 260 0.60
------------------------------------------------------------------------
\1\ Exempt from NOx standards and NOx monitoring requirements.
\2\ Any fuel containing less than 25%, by weight, lignite is not
prorated but its percentage is added to the percentage of the
predominant fuel.
(2) NOx reduction requirement.
------------------------------------------------------------------------
Percent
reduction of
Fuel type potential
combustion
concentration
------------------------------------------------------------------------
Gaseous fuels........................................... 25
Liquid fuels............................................ 30
Solid fuels............................................. 65
------------------------------------------------------------------------
(b) The emission limitations under paragraph (a) of this section do
not apply to any affected facility which is combusting coal-derived
liquid fuel and is operating under a commercial demonstration permit
issued by the Administrator in accordance with the provisions of
Sec. 60.45a.
(c) Except as provided under paragraph (d) of this section, when two
or more fuels are combusted simultaneously, the applicable standard is
determined by proration using the following formula:
En=[86 w+130 x +210 y+260 z+340 v]/100
where:
En is the applicable standard for nitrogen oxides when
multiple fuels are combusted simultaneously (ng/J heat input);
w is the percentage of total heat input derived from the combustion of
fuels subject to the 86 ng/J heat input standard;
x is the percentage of total heat input derived from the combustion of
fuels subject to the 130 ng/J heat input standard;
y is the percentage of total heat input derived from the combustion of
fuels subject to the 210 ng/J heat input standard;
[[Page 102]]
z is the percentage of total heat input derived from the combustion of
fuels subject to the 260 ng/J heat input standard; and
v is the percentage of total heat input delivered from the combustion of
fuels subject to the 340 ng/J heat input standard.
(d)(1) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is completed, no new source
owner or operator subject to the provisions of this subpart shall cause
to be discharged into the atmosphere from any affected facility for
which construction commenced after July 9, 1997 any gases which contain
nitrogen oxides (expressed as NO2) in excess of 200 nanograms
per joule (1.6 pounds per megawatt-hour) gross energy output, based on a
30-day rolling average, except as provided under Sec. 60.46a(k)(1).
(2) On and after the date on which the initial performance test
required to be conducted under Sec. 60.8 is completed, no existing
source owner or operator subject to the provisions of this subpart shall
cause to be discharged into the atmosphere from any affected facility
for which modification or reconstruction commenced after July 9, 1997
any gases which contain nitrogen oxides (expressed as NO2) in
excess of 65 ng/JI (0.15 pounds per million Btu) heat input,
based on a 30-day rolling average.
[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 63
FR 49453, Sept. 16, 1998; 66 FR 18551, Apr. 10, 2001]
Sec. 60.45a Commercial demonstration permit.
(a) An owner or operator of an affected facility proposing to
demonstrate an emerging technology may apply to the Administrator for a
commercial demonstration permit. The Administrator will issue a
commercial demonstration permit in accordance with paragraph (e) of this
section. Commercial demonstration permits may be issued only by the
Administrator, and this authority will not be delegated.
(b) An owner or operator of an affected facility that combusts solid
solvent refined coal (SRC-I) and who is issued a commercial
demonstration permit by the Administrator is not subject to the SO2
emission reduction requirements under Sec. 60.43a(c) but must, as a
minimum, reduce SO2 emissions to 20 percent of the potential
combustion concentration (80 percent reduction) for each 24-hour period
of steam generator operation and to less than 520 ng/J (1.20 lb/million
Btu) heat input on a 30-day rolling average basis.
(c) An owner or operator of a fluidized bed combustion electric
utility steam generator (atmospheric or pressurized) who is issued a
commercial demonstration permit by the Administrator is not subject to
the SO2 emission reduction requirements under Sec. 60.43a(a)
but must, as a minimum, reduce SO2 emissions to 15 percent of
the potential combustion concentration (85 percent reduction) on a 30-
day rolling average basis and to less than 520 ng/J (1.20 lb/million
Btu) heat input on a 30-day rolling average basis.
(d) The owner or operator of an affected facility that combusts
coal-derived liquid fuel and who is issued a commercial demonstration
permit by the Administrator is not subject to the applicable NOx
emission limitation and percent reduction under Sec. 60.44a(a) but must,
as a minimum, reduce emissions to less than 300 ng/J (0.70 lb/million
Btu) heat input on a 30-day rolling average basis.
(e) Commercial demonstration permits may not exceed the following
equivalent MW electrical generation capacity for any one technology
category, and the total equivalent MW electrical generation capacity for
all commercial demonstration plants may not exceed 15,000 MW.
------------------------------------------------------------------------
Equivalent
electrical
Technology Pollutant capacity (MW
electrical
output)
------------------------------------------------------------------------
Solid solvent refined coal (SRC I)........... SO2 6,000-10,000
Fluidized bed combustion (atmospheric)....... SO2 400-3,000
Fluidized bed combustion (pressurized)....... SO2 400-1,200
Coal liquification........................... NOx 750-10,000
---------------
Total allowable for all technologies..... ......... 15,000
------------------------------------------------------------------------
Sec. 60.46a Compliance provisions.
(a) Compliance with the particulate matter emission limitation under
Sec. 60.42a(a)(1) constitutes compliance
[[Page 103]]
with the percent reduction requirements for particulate matter under
Sec. 60.42a(a)(2) and (3).
(b) Compliance with the nitrogen oxides emission limitation under
Sec. 60.44a(a) constitutes compliance with the percent reduction
requirements under Sec. 60.44a(a)(2).
(c) The particulate matter emission standards under Sec. 60.42a and
the nitrogen oxides emission standards under Sec. 60.44a apply at all
times except during periods of startup, shutdown, or malfunction. The
sulfur dioxide emission standards under Sec. 60.43a apply at all times
except during periods of startup, shutdown, or when both emergency
conditions exist and the procedures under paragraph (d) of this section
are implemented.
(d) During emergency conditions in the principal company, an
affected facility with a malfunctioning flue gas desulfurization system
may be operated if sulfur dioxide emissions are minimized by:
(1) Operating all operable flue gas desulfurization system modules,
and bringing back into operation any malfunctioned module as soon as
repairs are completed,
(2) Bypassing flue gases around only those flue gas desulfurization
system modules that have been taken out of operation because they were
incapable of any sulfur dioxide emission reduction or which would have
suffered significant physical damage if they had remained in operation,
and
(3) Designing, constructing, and operating a spare flue gas
desulfurization system module for an affected facility larger than 365
MW (1,250 million Btu/hr) heat input (approximately 125 MW electrical
output capacity). The Administrator may at his discretion require the
owner or operator within 60 days of notification to demonstrate spare
module capability. To demonstrate this capability, the owner or operator
must demonstrate compliance with the appropriate requirements under
paragraph (a), (b), (d), (e), and (h) under Sec. 60.43a for any period
of operation lasting from 24 hours to 30 days when:
(i) Any one flue gas desulfurization module is not operated,
(ii) The affected facility is operating at the maximum heat input
rate,
(iii) The fuel fired during the 24-hour to 30-day period is
representative of the type and average sulfur content of fuel used over
a typical 30-day period, and
(iv) The owner or operator has given the Administrator at least 30
days notice of the date and period of time over which the demonstration
will be performed.
(e) After the initial performance test required under Sec. 60.8,
compliance with the sulfur dioxide emission limitations and percentage
reduction requirements under Sec. 60.43a and the nitrogen oxides
emission limitations under Sec. 60.44a is based on the average emission
rate for 30 successive boiler operating days. A separate performance
test is completed at the end of each boiler operating day after the
initial performance test, and a new 30 day average emission rate for
both sulfur dioxide and nitrogen oxides and a new percent reduction for
sulfur dioxide are calculated to show compliance with the standards.
(f) For the initial performance test required under Sec. 60.8,
compliance with the sulfur dioxide emission limitations and percent
reduction requirements under Sec. 60.43a and the nitrogen oxides
emission limitation under Sec. 60.44a is based on the average emission
rates for sulfur dioxide, nitrogen oxides, and percent reduction for
sulfur dioxide for the first 30 successive boiler operating days. The
initial performance test is the only test in which at least 30 days
prior notice is required unless otherwise specified by the
Administrator. The initial performance test is to be scheduled so that
the first boiler operating day of the 30 successive boiler operating
days is completed within 60 days after achieving the maximum production
rate at which the affected facility will be operated, but not later than
180 days after initial startup of the facility.
(g) Compliance is determined by calculating the arithmetic average
of all hourly emission rates for SO2 and NOx for
the 30 successive boiler operating days, except for data obtained during
startup, shutdown, malfunction (NOx only), or emergency
conditions (SO2 only). Compliance with the percentage
[[Page 104]]
reduction requirement for SO2 is determined based on the
average inlet and average outlet SO2 emission rates for the
30 successive boiler operating days.
(h) If an owner or operator has not obtained the minimum quantity of
emission data as required under Sec. 60.47a of this subpart, compliance
of the affected facility with the emission requirements under
Secs. 60.43a and 60.44a of this subpart for the day on which the 30-day
period ends may be determined by the Administrator by following the
applicable procedures in section 7 of Method 19.
(i) Compliance provisions for sources subject to Sec. 60.44a(d)(1).
The owner or operator of an affected facility subject to
Sec. 60.44a(d)(1) (new source constructed after July 7, 1997) shall
calculate NOX emissions by multiplying the average hourly
NOX output concentration, measured according to the
provisions of Sec. 60.47a(c), by the average hourly flow rate, measured
according to the provisions of Sec. 60.47a(l), and divided by the
average hourly gross energy output, measured according to the provisions
of Sec. 60.47a(k).
(j) Compliance provisions for duct burners subject to
Sec. 60.44a(a)(1). To determine compliance with the emissions limits for
NOX required by Sec. 60.44a(a) for duct burners used in
combined cycle systems, either of the procedures described in paragraph
(j)(1) or (2) of this section may be used:
(1) The owner or operator of an affected duct burner shall conduct
the performance test required under Sec. 60.8 using the appropriate
methods in appendix A of this part. Compliance with the emissions limits
under Sec. 60.44a(a)(1) is determined on the average of three (nominal
1-hour) runs for the initial and subsequent performance tests. During
the performance test, one sampling site shall be located in the exhaust
of the turbine prior to the duct burner. A second sampling site shall be
located at the outlet from the heat recovery steam generating unit.
Measurements shall be taken at both sampling sites during the
performance test; or
(2) The owner or operator of an affected duct burner may elect to
determine compliance by using the continuous emission monitoring system
specified under Sec. 60.47a for measuring NOX and oxygen and
meet the requirements of Sec. 60.47a. Data from a CEMS certified (or
recertified) according to the provisions of 40 CFR 75.20, meeting the QA
and QC requirements of 40 CFR 75.21, and validated according to 40 CFR
75.23 may be used. The sampling site shall be located at the outlet from
the steam generating unit. The NOX emission rate at the
outlet from the steam generating unit shall constitute the
NOX emission rate from the duct burner of the combined cycle
system.
(k) Compliance provisions for duct burners subject to
Sec. 60.44a(d)(1). To determine compliance with the emissions limits for
NOX required by Sec. 60.44a(d)(1) for duct burners used in
combined cycle systems, either of the procedures described in paragraphs
(k)(1) and (2) of this section may be used:
(1) The owner or operator of an affected duct burner used in
combined cycle systems shall determine compliance with the
NOX standard in Sec. 60.44a(d)(1) as follows:
(i) The emission rate (E) of NOX shall be computed using
Equation 1 of this section:
E = [(Csg x Qsg)-(Cte x Qte)]/(Osg x h) (Eq. 1)
Where:
E = emission rate of NOX from the duct burner, ng/J (lb/Mwh)
gross output
Csg = average hourly concentration of NOX exiting the steam
generating unit, ng/dscm (lb/dscf)
Cte = average hourly concentration of NOX in the turbine
exhaust upstream from duct burner, ng/dscm (lb/dscf)
Qsg = average hourly volumetric flow rate of exhaust gas from steam
generating unit, dscm/hr (dscf/hr)
Qte = average hourly volumetric flow rate of exhaust gas from combustion
turbine, dscm/hr (dscf/hr)
Osg = average hourly gross energy output from steam generating unit, J
(Mwh)
h = average hourly fraction of the total heat input to the steam
generating unit derived from the combustion of fuel in the
affected duct burner
(ii) Method 7E of appendix A of this part shall be used to determine
the NOX concentrations (Csg and Cte). Method 2, 2F or 2G of
appendix A of this part, as appropriate, shall be used to determine the
volumetric flow rates (Qsg and Qte) of the exhaust gases. The volumetric
flow rate measurements
[[Page 105]]
shall be taken at the same time as the concentration measurements.
(iii) The owner or operator shall develop, demonstrate, and provide
information satisfactory to the Administrator to determine the average
hourly gross energy output from the steam generating unit, and the
average hourly percentage of the total heat input to the steam
generating unit derived from the combustion of fuel in the affected duct
burner.
(iv) Compliance with the emissions limits under Sec. 60.44a (d)(1)
is determined by the three-run average (nominal 1-hour runs) for the
initial and subsequent performance tests.
(2) The owner or operator of an affected duct burner used in a
combined cycle system may elect to determine compliance with the
NOX standard in Sec. 60.44a(d)(1) on a 30-day rolling average
basis as indicated in paragraphs (k)(2)(i) through (iv) of this section.
(i) The emission rate (E) of NOX shall be computed using
Equation 2 of this section:
E = (Csg x Qsd) /Occ (Eq. 2)
Where:
E = emission rate of NOX from the duct burner, ng/J (lb/Mwh)
gross output
Csg = average hourly concentration of NOX exiting the steam
generating unit, ng/dscm (lb/dscf)
Qsg = average hourly volumetric flow rate of exhaust gas from steam
generating unit, dscm/hr (dscf/hr)
Occ = average hourly gross energy output from entire combined cycle
unit, J (Mwh)
(ii) The continuous emissions monitoring system specified under
Sec. 60.47a for measuring NOX and oxygen shall be used to
determine the average hourly NOX concentrations (Csg). The
continuous flow monitoring system specified in Sec. 60.47a(l) shall be
used to determine the volumetric flow rate (Qsg) of the exhaust gas. The
sampling site shall be located at the outlet from the steam generating
unit. Data from a continuous flow monitoring system certified (or
recertified) following procedures specified in 40 CFR 75.20, meeting the
quality assurance and quality control requirements of 40 CFR 75.21, and
validated according to 40 CFR 75.23 may be used.
(iii) The continuous monitoring system specified under
Sec. 60.47a(k) for measuring and determining gross energy output shall
be used to determine the average hourly gross energy output from the
entire combined cycle unit (Occ), which is the combined output from the
combustion turbine and the steam generating unit.
(iv) The owner or operator may, in lieu of installing, operating,
and recording data from the continuous flow monitoring system specified
in Sec. 60.47a(l), determine the mass rate (lb/hr) of NOX
emissions by installing, operating, and maintaining continuous fuel
flowmeters following the appropriate measurements procedures specified
in appendix D of 40 CFR part 75. If this compliance option is selected,
the emission rate (E) of NOX shall be computed using Equation
3 of this section:
E = (ERsg x Hcc) /Occ (Eq. 3)
Where:
E = emission rate of NOX from the duct burner, ng/J (lb/Mwh)
gross output
ERsg = average hourly emission rate of NOX exiting the steam
generating unit heat input calculated using appropriate F-
factor as described in Method 19, ng/J (lb/million Btu)
Hcc = average hourly heat input rate of entire combined cycle unit, J/hr
(million Btu/hr)
Occ = average hourly gross energy output from entire combined cycle
unit, J (Mwh)
(3) When an affected duct burner steam generating unit utilizes a
common steam turbine with one or more affected duct burner steam
generating units, the owner or operator shall either:
(i) Determine compliance with the applicable NOX
emissions limits by measuring the emissions combined with the emissions
from the other unit(s) utilizing the common steam turbine; or
(ii) Develop, demonstrate, and provide information satisfactory to
the Administrator on methods for apportioning the combined gross energy
output from the steam turbine for each of the affected duct burners. The
Administrator may approve such demonstrated substitute methods for
apportioning the combined gross energy output measured at the steam
turbine whenever the demonstration ensures
[[Page 106]]
accurate estimation of emissions regulated under this part.
[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 63
FR 49454, Sept. 16, 1998; 66 FR 18552, Apr. 10, 2001; 66 FR 31178, June
11, 2001]
Sec. 60.47a Emission monitoring.
(a) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous monitoring system, and
record the output of the system, for measuring the opacity of emissions
discharged to the atmosphere, except where gaseous fuel is the only fuel
combusted. If opacity interference due to water droplets exists in the
stack (for example, from the use of an FGD system), the opacity is
monitored upstream of the interference (at the inlet to the FGD system).
If opacity interference is experienced at all locations (both at the
inlet and outlet of the sulfur dioxide control system), alternate
parameters indicative of the particulate matter control system's
performance are monitored (subject to the approval of the
Administrator).
(b) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous monitoring system, and
record the output of the system, for measuring sulfur dioxide emissions,
except where natural gas is the only fuel combusted, as follows:
(1) Sulfur dioxide emissions are monitored at both the inlet and
outlet of the sulfur dioxide control device.
(2) For a facility which qualifies under the provisions of
Sec. 60.43a(d), sulfur dioxide emissions are only monitored as
discharged to the atmosphere.
(3) An ``as fired'' fuel monitoring system (upstream of coal
pulverizers) meeting the requirements of Method 19may be used to
determine potential sulfur dioxide emissions in place of a continuous
sulfur dioxide emission monitor at the inlet to the sulfur dioxide
control device as required under paragraph (b)(1) of this section.
(c)(1) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous monitoring system, and
record the output of the system, for measuring nitrogen oxides emissions
discharged to the atmosphere; or
(2) If the owner or operator has installed a nitrogen oxides
emission rate continuous emission monitoring system (CEMS) to meet the
requirements of part 75 of this chapter and is continuing to meet the
ongoing requirements of part 75 of this chapter, that CEMS may be used
to meet the requirements of this section, except that the owner or
operator shall also meet the requirements of Sec. 60.49a. Data reported
to meet the requirements of Sec. 60.49a shall not include data
substituted using the missing data procedures in subpart D of part 75 of
this chapter, nor shall the data have been bias adjusted according to
the procedures of part 75 of this chapter.
(d) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous monitoring system, and
record the output of the system, for measuring the oxygen or carbon
dioxide content of the flue gases at each location where sulfur dioxide
or nitrogen oxides emissions are monitored.
(e) The continuous monitoring systems under paragraphs (b), (c), and
(d) of this section are operated and data recorded during all periods of
operation of the affected facility including periods of startup,
shutdown, malfunction or emergency conditions, except for continuous
monitoring system breakdowns, repairs, calibration checks, and zero and
span adjustments.
(f) The owner or operator shall obtain emission data for at least 18
hours in at least 22 out of 30 successive boiler operating days. If this
minimum data requirement cannot be met with a continuous monitoring
system, the owner or operator shall supplement emission data with other
monitoring systems approved by the Administrator or the reference
methods and procedures as described in paragraph (h) of this section.
(g) The 1-hour averages required under paragraph Sec. 60.13(h) are
expressed in ng/J (lb/million Btu) heat input and used to calculate the
average emission rates under Sec. 60.46a. The 1-hour averages are
calculated using the data points required under Sec. 60.13(b). At least
[[Page 107]]
two data points must be used to calculate the 1-hour averages.
(h) When it becomes necessary to supplement continuous monitoring
system data to meet the minimum data requirements in paragraph (f) of
this section, the owner or operator shall use the reference methods and
procedures as specified in this paragraph. Acceptable alternative
methods and procedures are given in paragraph (j) of this section.
(1) Method 6 shall be used to determine the SO2
concentration at the same location as the SO2 monitor.
Samples shall be taken at 60-minute intervals. The sampling time and
sample volume for each sample shall be at least 20 minutes and 0.020
dscm (0.71 dscf). Each sample represents a 1-hour average.
(2) Method 7 shall be used to determine the NOx
concentration at the same location as the NOx monitor.
Samples shall be taken at 30-minute intervals. The arithmetic average of
two consecutive samples represents a 1-hour average.
(3) The emission rate correction factor, integrated bag sampling and
analysis procedure of Method 3B shall be used to determine the
O2 or CO2 concentration at the same location as
the O2 or CO2 monitor. Samples shall be taken for
at least 30 minutes in each hour. Each sample represents a 1-hour
average.
(4) The procedures in Method 19 shall be used to compute each 1-hour
average concentration in ng/J (1b/million Btu) heat input.
(i) The owner or operator shall use methods and procedures in this
paragraph to conduct monitoring system performance evaluations under
Sec. 60.13(c) and calibration checks under Sec. 60.13(d). Acceptable
alternative methods and procedures are given in paragraph (j) of this
section.
(1) Methods 3B, 6, and 7 shall be used to determine O2,
SO2, and NOX concentrations, respectively.
(2) SO2 or NOx (NO), as applicable, shall be
used for preparing the calibration gas mixtures (in N2, as
applicable) under Performance Specification 2 of appendix B of this
part.
(3) For affected facilities burning only fossil fuel, the span value
for a continuous monitoring system for measuring opacity is between 60
and 80 percent and for a continuous monitoring system measuring nitrogen
oxides is determined as follows:
------------------------------------------------------------------------
Span value for
Fossil fuel nitrogen oxides
(ppm)
------------------------------------------------------------------------
Gas............................................... 500
Liquid............................................ 500
Solid............................................. 1,000
Combination....................................... 500 (x+y)+1,000z
------------------------------------------------------------------------
where:
x is the fraction of total heat input derived from gaseous fossil fuel,
y is the fraction of total heat input derived from liquid fossil fuel,
and
z is the fraction of total heat input derived from solid fossil fuel.
(4) All span values computed under paragraph (b)(3) of this section
for burning combinations of fossil fuels are rounded to the nearest 500
ppm.
(5) For affected facilities burning fossil fuel, alone or in
combination with non-fossil fuel, the span value of the sulfur dioxide
continuous monitoring system at the inlet to the sulfur dioxide control
device is 125 percent of the maximum estimated hourly potential
emissions of the fuel fired, and the outlet of the sulfur dioxide
control device is 50 percent of maximum estimated hourly potential
emissions of the fuel fired.
(j) The owner or operator may use the following as alternatives to
the reference methods and procedures specified in this section:
(1) For Method 6, Method 6A or 6B (whenever Methods 6 and 3 or 3B
data are used) or 6C may be used. Each Method 6B sample obtained over 24
hours represents 24 1-hour averages. If Method 6A or 6B is used under
paragraph (i) of this section, the conditions under Sec. 60.46(d)(1)
apply; these conditions do not apply under paragraph (h) of this
section.
(2) For Method 7, Method 7A, 7C, 7D, or 7E may be used. If Method
7C, 7D, or 7E is used, the sampling time for each run shall be 1 hour.
(3) For Method 3, Method 3A or 3B may be used if the sampling time
is 1 hour.
(4) For Method 3B, Method 3A may be used.
(k) The procedures specified in paragraphs (k)(1) through (3) of
this section
[[Page 108]]
shall be used to determine gross output for sources demonstrating
compliance with the output-based standard under Sec. 60.44a(d)(1).
(1) The owner or operator of an affected facility with electricity
generation shall install, calibrate, maintain, and operate a wattmeter;
measure gross electrical output in megawatt-hour on a continuous basis;
and record the output of the monitor.
(2) The owner or operator of an affected facility with process steam
generation shall install, calibrate, maintain, and operate meters for
steam flow, temperature, and pressure; measure gross process steam
output in joules per hour (or Btu per hour) on a continuous basis; and
record the output of the monitor.
(3) For affected facilities generating process steam in combination
with electrical generation, the gross energy output is determined from
the gross electrical output measured in accordance with paragraph (k)(1)
of this section plus 50 percent of the gross thermal output of the
process steam measured in accordance with paragraph (k)(2) of this
section.
(l) The owner or operator of an affected facility demonstrating
compliance with the output-based standard under Sec. 60.44a(d)(1) shall
install, certify, operate, and maintain a continuous flow monitoring
system meeting the requirements of Performance Specification 6 of
appendix B and procedure 1 of appendix F of this subpart, and record the
output of the system, for measuring the flow of exhaust gases discharged
to the atmosphere; or
(m) Alternatively, data from a continuous flow monitoring system
certified according to the requirements of 40 CFR 75.20, meeting the
applicable quality control and quality assurance requirements of 40 CFR
75.21, and validated according to 40 CFR 75.23, may be used.
(n) Gas-fired and oil-fired units. The owner or operator of an
affected unit that qualifies as a gas-fired or oil-fired unit, as
defined in 40 CFR 72.2, may use, as an alternative to the requirements
specified in either paragraph (l) or (m) of this section, a fuel flow
monitoring system certified and operated according to the requirements
of appendix D of 40 CFR part 75.
(o) The owner or operator of a duct burner, as described in
Sec. 60.41a, which is subject to the NOX standards of
Sec. 60.44a(a)(1) or (d)(1) is not required to install or operate a
continuous emissions monitoring system to measure NOX
emissions; a wattmeter to measure gross electrical output; meters to
measure steam flow, temperature, and pressure; and a continuous flow
monitoring system to measure the flow of exhaust gases discharged to the
atmosphere.
[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 55
FR 5212, Feb. 14, 1990; 55 FR 18876, May 7, 1990; 63 FR 49454, Sept. 16,
1998; 65 FR 61752, Oct. 17, 2000; 66 FR 18553, Apr. 10, 2001]
Sec. 60.48a Compliance determination procedures and methods.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the
methods in appendix A of this part or the methods and procedures as
specified in this section, except as provided in Sec. 60.8(b). Section
60.8(f) does not apply to this section for SO2 and
NOx. Acceptable alternative methods are given in paragraph
(e) of this section.
(b) The owner or operator shall determine compliance with the
particulate matter standards in Sec. 60.42a as follows:
(1) The dry basis F factor (O2) procedures in Method 19
shall be used to compute the emission rate of particulate matter.
(2) For the particular matter concentration, Method 5 shall be used
at affected facilities without wet FGD systems and Method 5B shall be
used after wet FGD systems.
(i) The sampling time and sample volume for each run shall be at
least 120 minutes and 1.70 dscm (60 dscf). The probe and filter holder
heating system in the sampling train may be set to provide an average
gas temperature of no greater than 16014 deg. C
(32025 deg. F).
(ii) For each particulate run, the emission rate correction factor,
integrated or grab sampling and analysis procedures of Method 3B shall
be used to determine the O2 concentration. The
[[Page 109]]
O2 sample shall be obtained simultaneously with, and at the
same traverse points as, the particulate run. If the particulate run has
more than 12 traverse points, the O2 traverse points may be
reduced to 12 provided that Method 1 is used to locate the 12
O2 traverse points. If the grab sampling procedure is used,
the O2 concentration for the run shall be the arithmetic mean
of the sample O2 concentrations at all traverse points.
(3) Method 9 and the procedures in Sec. 60.11 shall be used to
determine opacity.
(c) The owner or operator shall determine compliance with the
SO2 standards in Sec. 60.43a as follows:
(1) The percent of potential SO2 emissions
(%Ps) to the atmosphere shall be computed using the following
equation:
%Ps=[(100--%Rf) (100--%Rg)]/100
where:
%Ps=percent of potential SO2 emissions, percent.
%Rf=percent reduction from fuel pretreatment, percent.
%Rg=percent reduction by SO2 control system,
percent.
(2) The procedures in Method 19 may be used to determine percent
reduction (%Rf) of sulfur by such processes as fuel
pretreatment (physical coal cleaning, hydrodesulfurization of fuel oil,
etc.), coal pulverizers, and bottom and flyash interactions. This
determination is optional.
(3) The procedures in Method 19 shall be used to determine the
percent SO2 reduction (%Rg) of any SO2
control system. Alternatively, a combination of an ``as fired'' fuel
monitor and emission rates measured after the control system, following
the procedures in Method 19, may be used if the percent reduction is
calculated using the average emission rate from the SO2
control device and the average SO2 input rate from the ``as
fired'' fuel analysis for 30 successive boiler operating days.
(4) The appropriate procedures in Method 19 shall be used to
determine the emission rate.
(5) The continuous monitoring system in Sec. 60.47a (b) and (d)
shall be used to determine the concentrations of SO2 and
CO2 or O2.
(d) The owner or operator shall determine compliance with the
NOx standard in Sec. 60.44a as follows:
(1) The appropriate procedures in Method 19 shall be used to
determine the emission rate of NOx.
(2) The continous monitoring system in Sec. 60.47a (c) and (d) shall
be used to determine the concentrations of NOx and
CO2 or O2.
(e) The owner or operator may use the following as alternatives to
the reference methods and procedures specified in this section:
(1) For Method 5 or 5B, Method 17 may be used at facilities with or
without wet FGD systems if the stack temperature at the sampling
location does not exceed an average temperature of 160 deg.C (320
deg.F). The procedures of Secs. 2.1 and 2.3 of Method 5B may be used in
Method 17 only if it is used after wet FGD systems. Method 17 shall not
be used after wet FGD systems if the effluent is saturated or laden with
water droplets.
(2) The Fc factor (CO2) procedures in Method
19 may be used to compute the emission rate of particulate matter under
the stipulations of Sec. 60.46(d)(1). The CO2 shall be
determined in the same manner as the O2 concentration.
(f) Electric utility combined cycle gas turbines are performance
tested for particulate matter, sulfur dioxide, and nitrogen oxides using
the procedures of Method 19. The sulfur dioxide and nitrogen oxides
emission rates from the gas turbine used in Method 19 calculations are
determined when the gas turbine is performance tested under subpart GG.
The potential uncontrolled particulate matter emission rate from a gas
turbine is defined as 17 ng/J (0.04 lb/million Btu) heat input.
[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 55
FR 5212, Feb. 14, 1990; 65 FR 61752, Oct. 17, 2000]
Sec. 60.49a Reporting requirements.
(a) For sulfur dioxide, nitrogen oxides, and particulate matter
emissions, the performance test data from the initial performance test
and from the performance evaluation of the continuous monitors
(including the transmissometer) are submitted to the Administrator.
[[Page 110]]
(b) For sulfur dioxide and nitrogen oxides the following information
is reported to the Administrator for each 24-hour period.
(1) Calendar date.
(2) The average sulfur dioxide and nitrogen oxide emission rates
(ng/J or lb/million Btu) for each 30 successive boiler operating days,
ending with the last 30-day period in the quarter; reasons for non-
compliance with the emission standards; and, description of corrective
actions taken.
(3) Percent reduction of the potential combustion concentration of
sulfur dioxide for each 30 successive boiler operating days, ending with
the last 30-day period in the quarter; reasons for non-compliance with
the standard; and, description of corrective actions taken.
(4) Identification of the boiler operating days for which pollutant
or dilutent data have not been obtained by an approved method for at
least 18 hours of operation of the facility; justification for not
obtaining sufficient data; and description of corrective actions taken.
(5) Identification of the times when emissions data have been
excluded from the calculation of average emission rates because of
startup, shutdown, malfunction (NOx only), emergency
conditions (SO2 only), or other reasons, and justification
for excluding data for reasons other than startup, shutdown,
malfunction, or emergency conditions.
(6) Identification of ``F'' factor used for calculations, method of
determination, and type of fuel combusted.
(7) Identification of times when hourly averages have been obtained
based on manual sampling methods.
(8) Identification of the times when the pollutant concentration
exceeded full span of the continuous monitoring system.
(9) Description of any modifications to the continuous monitoring
system which could affect the ability of the continuous monitoring
system to comply with Performance Specifications 2 or 3.
(c) If the minimum quantity of emission data as required by
Sec. 60.47a is not obtained for any 30 successive boiler operating days,
the following information obtained under the requirements of
Sec. 60.46a(h) is reported to the Administrator for that 30-day period:
(1) The number of hourly averages available for outlet emission
rates (no) and inlet emission rates (ni) as
applicable.
(2) The standard deviation of hourly averages for outlet emission
rates (so) and inlet emission rates (si) as
applicable.
(3) The lower confidence limit for the mean outlet emission rate
(Eo*) and the upper confidence limit for the mean inlet
emission rate (Ei*) as applicable.
(4) The applicable potential combustion concentration.
(5) The ratio of the upper confidence limit for the mean outlet
emission rate (Eo*) and the allowable emission rate
(Estd) as applicable.
(d) If any standards under Sec. 60.43a are exceeded during emergency
conditions because of control system malfunction, the owner or operator
of the affected facility shall submit a signed statement:
(1) Indicating if emergency conditions existed and requirements
under Sec. 60.46a(d) were met during each period, and
(2) Listing the following information:
(i) Time periods the emergency condition existed;
(ii) Electrical output and demand on the owner or operator's
electric utility system and the affected facility;
(iii) Amount of power purchased from interconnected neighboring
utility companies during the emergency period;
(iv) Percent reduction in emissions achieved;
(v) Atmospheric emission rate (ng/J) of the pollutant discharged;
and
(vi) Actions taken to correct control system malfunction.
(e) If fuel pretreatment credit toward the sulfur dioxide emission
standard under Sec. 60.43a is claimed, the owner or operator of the
affected facility shall submit a signed statement:
(1) Indicating what percentage cleaning credit was taken for the
calendar quarter, and whether the credit was determined in accordance
with the provisions of Sec. 60.48a and Method 19 (appendix A); and
[[Page 111]]
(2) Listing the quantity, heat content, and date each pretreated
fuel shipment was received during the previous quarter; the name and
location of the fuel pretreatment facility; and the total quantity and
total heat content of all fuels received at the affected facility during
the previous quarter.
(f) For any periods for which opacity, sulfur dioxide or nitrogen
oxides emissions data are not available, the owner or operator of the
affected facility shall submit a signed statement indicating if any
changes were made in operation of the emission control system during the
period of data unavailability. Operations of the control system and
affected facility during periods of data unavailability are to be
compared with operation of the control system and affected facility
before and following the period of data unavailability.
(g) The owner or operator of the affected facility shall submit a
signed statement indicating whether:
(1) The required continuous monitoring system calibration, span, and
drift checks or other periodic audits have or have not been performed as
specified.
(2) The data used to show compliance was or was not obtained in
accordance with approved methods and procedures of this part and is
representative of plant performance.
(3) The minimum data requirements have or have not been met; or, the
minimum data requirements have not been met for errors that were
unavoidable.
(4) Compliance with the standards has or has not been achieved
during the reporting period.
(h) For the purposes of the reports required under Sec. 60.7,
periods of excess emissions are defined as all 6-minute periods during
which the average opacity exceeds the applicable opacity standards under
Sec. 60.42a(b). Opacity levels in excess of the applicable opacity
standard and the date of such excesses are to be submitted to the
Administrator each calendar quarter.
(i) The owner or operator of an affected facility shall submit the
written reports required under this section and subpart A to the
Administrator semiannually for each six-month period. All semiannual
reports shall be postmarked by the 30th day following the end of each
six-month period.
(j) The owner or operator of an affected facility may submit
electronic quarterly reports for SO2 and/or NOX
and/or opacity in lieu of submitting the written reports required under
paragraphs (b) and (h) of this section. The format of each quarterly
electronic report shall be coordinated with the permitting authority.
The electronic report(s) shall be submitted no later than 30 days after
the end of the calendar quarter and shall be accompanied by a
certification statement from the owner or operator, indicating whether
compliance with the applicable emission standards and minimum data
requirements of this subpart was achieved during the reporting period.
Before submitting reports in the electronic format, the owner or
operator shall coordinate with the permitting authority to obtain their
agreement to submit reports in this alternative format.
[44 FR 33613, June 11, 1979, as amended at 63 FR 49454, Sept. 16, 1998;
64 FR 7464, Feb. 12, 1999]
Subpart Db--Standards of Performance for Industrial-Commercial-
Institutional Steam Generating Units
Sec. 60.40b Applicability and delegation of authority.
(a) The affected facility to which this subpart applies is each
steam generating unit that commences construction, modification, or
reconstruction after June 19, 1984, and that has a heat input capacity
from fuels combusted in the steam generating unit of greater than 29 MW
(100 million Btu/hour).
(b) Any affected facility meeting the applicability requirements
under paragraph (a) of this section and commencing construction,
modification, or reconstruction after June 19, 1984, but on or before
June 19, 1986, is subject to the following standards:
(1) Coal-fired affected facilities having a heat input capacity
between 29 and 73 MW (100 and 250 million Btu/hour), inclusive, are
subject to the particulate matter and nitrogen oxides standards under
this subpart.
[[Page 112]]
(2) Coal-fired affected facilities having a heat input capacity
greater than 73 MW (250 million Btu/hour) and meeting the applicability
requirements under subpart D (Standards of performance for fossil-fuel-
fired steam generators; Sec. 60.40) are subject to the particulate
matter and nitrogen oxides standards under this subpart and to the
sulfur dioxide standards under subpart D (Sec. 60.43).
(3) Oil-fired affected facilities having a heat input capacity
between 29 and 73 MW (100 and 250 million Btu/hour), inclusive, are
subject to the nitrogen oxides standards under this subpart.
(4) Oil-fired affected facilities having a heat input capacity
greater than 73 MW (250 million Btu/hour) and meeting the applicability
requirements under subpart D (Standards of performance for fossil-fuel-
fired steam generators; Sec. 60.40) are also subject to the nitrogen
oxides standards under this subpart and the particulate matter and
sulfur dioxide standards under subpart D (Sec. 60.42 and Sec. 60.43).
(c) Affected facilities which also meet the applicability
requirements under subpart J (Standards of performance for petroleum
refineries; Sec. 60.104) are subject to the particulate matter and
nitrogen oxides standards under this subpart and the sulfur dioxide
standards under subpart J (Sec. 60.104).
(d) Affected facilities which also meet the applicability
requirements under subpart E (Standards of performance for incinerators;
Sec. 60.50) are subject to the nitrogen oxides and particulate matter
standards under this subpart.
(e) Steam generating units meeting the applicability requirements
under subpart Da (Standards of performance for electric utility steam
generating units; Sec. 60.40a) are not subject to this subpart.
(f) Any change to an existing steam generating unit for the sole
purpose of combusting gases containing TRS as defined under Sec. 60.281
is not considered a modification under Sec. 60.14 and the steam
generating unit is not subject to this subpart.
(g) In delegating implementation and enforcement authority to a
State under section 111(c) of the Act, the following authorities shall
be retained by the Administrator and not transferred to a State.
(1) Section 60.44b(f).
(2) Section 60.44b(g).
(3) Section 60.49b(a)(4).
(h) Affected facilities which meet the applicability requirements
under subpart Eb (Standards of performance for municipal waste
combustors; Sec. 60.50b) are not subject to this subpart.
(i) Unless and until subpart GG of this part is revised to extend
the applicability of subpart GG of this part to steam generator units
subject to this subpart, this subpart will continue to apply to combined
cycle gas turbines that are capable of combusting more than 29 MW (100
million Btu/hour) heat input of fossil fuel in the steam generator. Only
emissions resulting from combustion of fuels in the steam generating
unit are subject to this subpart. (The gas turbine emissions are subject
to subpart GG of this part.)
(j) Any affected facility meeting the applicability requirements
under paragraph (a) of this section and commencing construction,
modification, or reconstruction after June 19, 1986 is not subject to
Subpart D (Standards of Performance for Fossil-Fuel-Fired Steam
Generators, Sec. 60.40).
[52 FR 47842, Dec. 16, 1987, as amended at 63 FR 49454, Sept. 16, 1998;
65 FR 61752, Oct. 17, 2000]
Sec. 60.41b Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
Annual capacity factor means the ratio between the actual heat input
to a steam generating unit from the fuels listed in Sec. 60.42b(a),
Sec. 60.43b(a), or Sec. 60.44b(a), as applicable, during a calendar year
and the potential heat input to the steam generating unit had it been
operated for 8,760 hours during a calendar year at the maximum steady
state design heat input capacity. In the case of steam generating units
that are rented or leased, the actual heat input shall be determined
based on the combined heat input from all operations of the affected
facility in a calendar year.
[[Page 113]]
Byproduct/waste means any liquid or gaseous substance produced at
chemical manufacturing plants or petroleum refineries (except natural
gas, distillate oil, or residual oil) and combusted in a steam
generating unit for heat recovery or for disposal. Gaseous substances
with carbon dioxide levels greater than 50 percent or carbon monoxide
levels greater than 10 percent are not byproduct/waste for the purposes
of this subpart.
Chemical manufacturing plants means industrial plants which are
classified by the Department of Commerce under Standard Industrial
Classification (SIC) Code 28.
Coal means all solid fuels classified as anthracite, bituminous,
subbituminous, or lignite by the American Society of Testing and
Materials in ASTM D388-77, 90, 91, 95, or 98a, Standard Specification
for Classification of Coals by Rank (IBR--see Sec. 60.17), coal refuse,
and petroleum coke. Coal-derived synthetic fuels, including but not
limited to solvent refined coal, gasified coal, coal-oil mixtures, and
coal-water mixtures, are also included in this definition for the
purposes of this subpart.
Coal refuse means any byproduct of coal mining or coal cleaning
operations with an ash content greater than 50 percent, by weight, and a
heating value less than 13,900 kJ/kg (6,000 Btu/lb) on a dry basis.
Combined cycle system means a system in which a separate source,
such as a gas turbine, internal combustion engine, kiln, etc., provides
exhaust gas to a heat recovery steam generating unit.
Conventional technology means wet flue gas desulfurization (FGD)
technology, dry FGD technology, atmospheric fluidized bed combustion
technology, and oil hydrodesulfurization technology.
Distillate oil means fuel oils that contain 0.05 weight percent
nitrogen or less and comply with the specifications for fuel oil numbers
1 and 2, as defined by the American Society of Testing and Materials in
ASTM D396-78, 89, 90, 92, 96, or 98, Standard Specifications for Fuel
Oils (incorporated by reference--see Sec. 60.17).
Dry flue gas desulfurization technology means a sulfur dioxide
control system that is located downstream of the steam generating unit
and removes sulfur oxides from the combustion gases of the steam
generating unit by contacting the combustion gases with an alkaline
slurry or solution and forming a dry powder material. This definition
includes devices where the dry powder material is subsequently converted
to another form. Alkaline slurries or solutions used in dry flue gas
desulfurization technology include but are not limited to lime and
sodium.
Duct burner means a device that combusts fuel and that is placed in
the exhaust duct from another source, such as a stationary gas turbine,
internal combustion engine, kiln, etc., to allow the firing of
additional fuel to heat the exhaust gases before the exhaust gases enter
a heat recovery steam generating unit.
Emerging technology means any sulfur dioxide control system that is
not defined as a conventional technology under this section, and for
which the owner or operator of the facility has applied to the
Administrator and received approval to operate as an emerging technology
under Sec. 60.49b(a)(4).
Federally enforceable means all limitations and conditions that are
enforceable by the Administrator, including the requirements of 40 CFR
parts 60 and 61, requirements within any applicable State Implementation
Plan, and any permit requirements established under 40 CFR 52.21 or
under 40 CFR 51.18 and 40 CFR 51.24.
Fluidized bed combustion technology means combustion of fuel in a
bed or series of beds (including but not limited to bubbling bed units
and circulating bed units) of limestone aggregate (or other sorbent
materials) in which these materials are forced upward by the flow of
combustion air and the gaseous products of combustion.
Fuel pretreatment means a process that removes a portion of the
sulfur in a fuel before combustion of the fuel in a steam generating
unit.
Full capacity means operation of the steam generating unit at 90
percent or more of the maximum steady-state design heat input capacity.
Heat input means heat derived from combustion of fuel in a steam
generating unit and does not include the
[[Page 114]]
heat input from preheated combustion air, recirculated flue gases, or
exhaust gases from other sources, such as gas turbines, internal
combustion engines, kilns, etc.
Heat release rate means the steam generating unit design heat input
capacity (in MW or Btu/hour) divided by the furnace volume (in cubic
meters or cubic feet); the furnace volume is that volume bounded by the
front furnace wall where the burner is located, the furnace side
waterwall, and extending to the level just below or in front of the
first row of convection pass tubes.
Heat transfer medium means any material that is used to transfer
heat from one point to another point.
High heat release rate means a heat release rate greater than
730,000 J/sec-m\3\ (70,000 Btu/hour-ft\3\).
Lignite means a type of coal classified as lignite A or lignite B by
the American Society of Testing and Materials in ASTM D388-77, 90, 91,
95, or 98a, Standard Specification for Classification of Coals by Rank
(IBR--see Sec. 60.17).
Low heat release rate means a heat release rate of 730,000 J/sec-
m\3\ (70,000 Btu/hour-ft\3\) or less.
Mass-feed stoker steam generating unit means a steam generating unit
where solid fuel is introduced directly into a retort or is fed directly
onto a grate where it is combusted.
Maximum heat input capacity means the ability of a steam generating
unit to combust a stated maximum amount of fuel on a steady state basis,
as determined by the physical design and characteristics of the steam
generating unit.
Municipal-type solid waste means refuse, more than 50 percent of
which is waste consisting of a mixture of paper, wood, yard wastes, food
wastes, plastics, leather, rubber, and other combustible materials, and
noncombustible materials such as glass and rock.
Natural gas means (1) a naturally occurring mixture of hydrocarbon
and nonhydrocarbon gases found in geologic formations beneath the
earth's surface, of which the principal constituent is methane; or (2)
liquid petroleum gas, as defined by the American Society for Testing and
Materials in ASTM D1835-82, 86, 87, 91, or 97, ``Standard Specification
for Liquid Petroleum Gases'' (IBR--see Sec. 60.17).
Noncontinental area means the State of Hawaii, the Virgin Islands,
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern
Mariana Islands.
Oil means crude oil or petroleum or a liquid fuel derived from crude
oil or petroleum, including distillate and residual oil.
Petroleum refinery means industrial plants as classified by the
Department of Commerce under Standard Industrial Classification (SIC)
Code 29.
Potential sulfur dioxide emission rate means the theoretical sulfur
dioxide emissions (ng/J, lb/million Btu heat input) that would result
from combusting fuel in an uncleaned state and without using emission
control systems.
Process heater means a device that is primarily used to heat a
material to initiate or promote a chemical reaction in which the
material participates as a reactant or catalyst.
Pulverized coal-fired steam generating unit means a steam generating
unit in which pulverized coal is introduced into an air stream that
carries the coal to the combustion chamber of the steam generating unit
where it is fired in suspension. This includes both conventional
pulverized coal-fired and micropulverized coal-fired steam generating
units.
Residual oil means crude oil, fuel oil numbers 1 and 2 that have a
nitrogen content greater than 0.05 weight percent, and all fuel oil
numbers 4, 5 and 6, as defined by the American Society of Testing and
Materials in ASTM D396-78, Standard Specifications for Fuel Oils (IBR--
see Sec. 60.17).
Spreader stoker steam generating unit means a steam generating unit
in which solid fuel is introduced to the combustion zone by a mechanism
that throws the fuel onto a grate from above. Combustion takes place
both in suspension and on the grate.
Steam generating unit means a device that combusts any fuel or
byproduct/waste to produce steam or to heat water or any other heat
transfer medium. This term includes any municipal-type solid waste
incinerator with a heat recovery steam generating unit or
[[Page 115]]
any steam generating unit that combusts fuel and is part of a
cogeneration system or a combined cycle system. This term does not
include process heaters as they are defined in this subpart.
Steam generating unit operating day means a 24-hour period between
12:00 midnight and the following midnight during which any fuel is
combusted at any time in the steam generating unit. It is not necessary
for fuel to be combusted continuously for the entire 24-hour period.
Very low sulfur oil means an oil that contains no more than 0.5
weight percent sulfur or that, when combusted without sulfur dioxide
emission control, has a sulfur dioxide emission rate equal to or less
than 215 ng/J (0.5 lb/million Btu) heat input.
Wet flue gas desulfurization technology means a sulfur dioxide
control system that is located downstream of the steam generating unit
and removes sulfur oxides from the combustion gases of the steam
generating unit by contacting the combustion gas with an alkaline slurry
or solution and forming a liquid material. This definition applies to
devices where the aqueous liquid material product of this contact is
subsequently converted to other forms. Alkaline reagents used in wet
flue gas desulfurization technology include, but are not limited to,
lime, limestone, and sodium.
Wet scrubber system means any emission control device that mixes an
aqueous stream or slurry with the exhaust gases from a steam generating
unit to control emissions of particulate matter or sulfur dioxide.
Wood means wood, wood residue, bark, or any derivative fuel or
residue thereof, in any form, including, but not limited to, sawdust,
sanderdust, wood chips, scraps, slabs, millings, shavings, and processed
pellets made from wood or other forest residues.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989;
65 FR 61752, Oct. 17, 2000]
Sec. 60.42b Standard for sulfur dioxide.
(a) Except as provided in paragraphs (b), (c), (d), or (j) of this
section, on and after the date on which the performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts coal or oil shall cause to be discharged into the
atmosphere any gases that contain sulfur dioxide in excess of 10 percent
(0.10) of the potential sulfur dioxide emission rate (90 percent
reduction) and that contain sulfur dioxide in excess of the emission
limit determined according to the following formula:
Es=(Ka Ha+Kb Hb)/
(Ha+Hb)
where:
Es is the sulfur dioxide emission limit, in ng/J or lb/
million Btu heat input,
Ka is 520 ng/J (or 1.2 lb/million Btu),
Kb is 340 ng/J (or 0.80 lb/million Btu),
Ha is the heat input from the combustion of coal, in J
(million Btu),
Hb is the heat input from the combustion of oil, in J
(million Btu).
Only the heat input supplied to the affected facility from the
combustion of coal and oil is counted under this section. No credit is
provided for the heat input to the affected facility from the combustion
of natural gas, wood, municipal-type solid waste, or other fuels or heat
input to the affected facility from exhaust gases from another source,
such as gas turbines, internal combustion engines, kilns, etc.
(b) On and after the date on which the performance test is completed
or required to be completed under Sec. 60.8 of this part, whichever
comes first, no owner or operator of an affected facility that combusts
coal refuse alone in a fluidized bed combustion steam generating unit
shall cause to be discharged into the atmosphere any gases that contain
sulfur dioxide in excess of 20 percent of the potential sulfur dioxide
emission rate (80 percent reduction) and that contain sulfur dioxide in
excess of 520 ng/J (1.2 lb/million Btu) heat input. If coal or oil is
fired with coal refuse, the affected facility is subject to paragraph
(a) or (d) of this section, as applicable.
(c) On and after the date on which the performance test is completed
or is required to be completed under Sec. 60.8 of this part, whichever
comes first, no owner or operator of an affected facility that combusts
coal or oil, either alone or in combination with any other
[[Page 116]]
fuel, and that uses an emerging technology for the control of sulfur
dioxide emissions, shall cause to be discharged into the atmosphere any
gases that contain sulfur dioxide in excess of 50 percent of the
potential sulfur dioxide emission rate (50 percent reduction) and that
contain sulfur dioxide in excess of the emission limit determined
according to the following formula:
Es=(Kc Hc+Kd Hd)/
Hc+Hd)
where:
Es is the sulfur dioxide emission limit, expressed in ng/J
(lb/million Btu) heat input,
Kc is 260 ng/J (0.60 lb/million Btu),
Kd is 170 ng/J (0.40 lb/million Btu),
Hc is the heat input from the combustion of coal, J (million
Btu),
Hd is the heat input from the combustion of oil, J (million
Btu).
Only the heat input supplied to the affected facility from the
combustion of coal and oil is counted under this section. No credit is
provided for the heat input to the affected facility from the combustion
of natural gas, wood, municipal-type solid waste, or other fuels, or
from the heat input to the affected facility from exhaust gases from
another source, such as gas turbines, internal combustion engines,
kilns, etc.
(d) On and after the date on which the performance test is completed
or required to be completed under Sec. 60.8 of this part, whichever
comes first, no owner or operator of an affected facility listed in
paragraphs (d) (1), (2), or (3) of this section shall cause to be
discharged into the atmosphere any gases that contain sulfur dioxide in
excess of 520 ng/J (1.2 lb/million Btu) heat input if the affected
facility combusts coal, or 215 ng/J (0.5 lb/million Btu) heat input if
the affected facility combusts oil other than very low sulfur oil.
Percent reduction requirements are not applicable to affected facilities
under paragraphs (d)(1), (2), or (3).
(1) Affected facilities that have an annual capacity factor for coal
and oil of 30 percent (0.30) or less and are subject to a Federally
enforceable permit limiting the operation of the affected facility to an
annual capacity factor for coal and oil of 30 percent (0.30) or less;
(2) Affected facilities located in a noncontinental area; or
(3) Affected facilities combusting coal or oil, alone or in
combination with any other fuel, in a duct burner as part of a combined
cycle system where 30 percent (0.30) or less of the heat input to the
steam generating unit is from combustion of coal and oil in the duct
burner and 70 percent (0.70) or more of the heat input to the steam
generating unit is from the exhaust gases entering the duct burner.
(e) Except as provided in paragraph (f) of this section, compliance
with the emission limits, fuel oil sulfur limits, and/or percent
reduction requirements under this section are determined on a 30-day
rolling average basis.
(f) Except as provided in paragraph (j)(2) of this section,
compliance with the emission limits or fuel oil sulfur limits under this
section is determined on a 24-hour average basis for affected facilities
that (1) have a Federally enforceable permit limiting the annual
capacity factor for oil to 10 percent or less, (2) combust only very low
sulfur oil, and (3) do not combust any other fuel.
(g) Except as provided in paragraph (i) of this section, the sulfur
dioxide emission limits and percent reduction requirements under this
section apply at all times, including periods of startup, shutdown, and
malfunction.
(h) Reductions in the potential sulfur dioxide emission rate through
fuel pretreatment are not credited toward the percent reduction
requirement under paragraph (c) of this section unless:
(1) Fuel pretreatment results in a 50 percent or greater reduction
in potential sulfur dioxide emissions and
(2) Emissions from the pretreated fuel (without combustion or post
combustion sulfur dioxide control) are equal to or less than the
emission limits specified in paragraph (c) of this section.
(i) An affected facility subject to paragraph (a), (b), or (c) of
this section may combust very low sulfur oil or natural gas when the
sulfur dioxide control system is not being operated because of
malfunction or maintenance of the sulfur dioxide control system.
(j) Percent reduction requirements are not applicable to affected
facilities combusting only very low sulfur oil.
[[Page 117]]
The owner or operator of an affected facility combusting very low sulfur
oil shall demonstrate that the oil meets the definition of very low
sulfur oil by: (1) Following the performance testing procedures as
described in Sec. 60.45b(c) or Sec. 60.45b(d), and following the
monitoring procedures as described in Sec. 60.47b(a) or Sec. 60.47b(b)
to determine sulfur dioxide emission rate or fuel oil sulfur content; or
(2) maintaining fuel receipts as described in Sec. 60.49b(r).
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989;
65 FR 61752, Oct. 17, 2000]
Sec. 60.43b Standard for particulate matter.
(a) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever comes first, no owner or operator of an affected facility
which combusts coal or combusts mixtures of coal with other fuels, shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain particulate matter in excess of the following
emission limits:
(1) 22 ng/J (0.051 lb/million Btu) heat input,
(i) If the affected facility combusts only coal, or
(ii) If the affected facility combusts coal and other fuels and has
an annual capacity factor for the other fuels of 10 percent (0.10) or
less.
(2) 43 ng/J (0.10 lb/million Btu) heat input if the affected
facility combusts coal and other fuels and has an annual capacity factor
for the other fuels greater than 10 percent (0.10) and is subject to a
federally enforceable requirement limiting operation of the affected
facility to an annual capacity factor greater than 10 percent (0.10) for
fuels other than coal.
(3) 86 ng/J (0.20 lb/million Btu) heat input if the affected
facility combusts coal or coal and other fuels and
(i) Has an annual capacity factor for coal or coal and other fuels
of 30 percent (0.30) or less,
(ii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less,
(iii) Has a federally enforceable requirement limiting operation of
the affected facility to an annual capacity factor of 30 percent (0.30)
or less for coal or coal and other solid fuels, and
(iv) Construction of the affected facility commenced after June 19,
1984, and before November 25, 1986.
(b) On and after the date on which the performance test is completed
or required to be completed under 60.8 of this part, whichever date
comes first, no owner or operator of an affected facility that combusts
oil (or mixtures of oil with other fuels) and uses a conventional or
emerging technology to reduce sulfur dioxide emissions shall cause to be
discharged into the atmosphere from that affected facility any gases
that contain particulate matter in excess of 43 ng/J (0.10 lb/million
Btu) heat input.
(c) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts wood, or wood with other fuels, except coal, shall cause
to be discharged from that affected facility any gases that contain
particulate matter in excess of the following emission limits:
(1) 43 ng/J (0.10 lb/million Btu) heat input if the affected
facility has an annual capacity factor greater than 30 percent (0.30)
for wood.
(2) 86 ng/J (0.20 lb/million Btu) heat input if
(i) The affected facility has an annual capacity factor of 30
percent (0.30) or less for wood,
(ii) Is subject to a federally enforceable requirement limiting
operation of the affected facility to an annual capacity factor of 30
percent (0.30) or less for wood, and
(iii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less.
(d) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts municipal-type solid waste or mixtures of municipal-type
solid waste with other fuels, shall cause to be discharged into
[[Page 118]]
the atmosphere from that affected facility any gases that contain
particulate matter in excess of the following emission limits:
(1) 43 ng/J (0.10 lb/million Btu) heat input,
(i) If the affected facility combusts only municipal-type solid
waste, or
(ii) If the affected facility combusts municipal-type solid waste
and other fuels and has an annual capacity factor for the other fuels of
10 percent (0.10) or less.
(2) 86 ng/J (0.20 lb/million Btu) heat input if the affected
facility combusts municipal-type solid waste or municipal-type solid
waste and other fuels; and
(i) Has an annual capacity factor for municipal-type solid waste and
other fuels of 30 percent (0.30) or less,
(ii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less,
(iii) Has a federally enforceable requirement limiting operation of
the affected facility to an annual capacity factor of 30 percent (0.30)
for municipal-type solid waste, or municipal-type solid waste and other
fuels, and
(iv) Construction of the affected facility commenced after June 19,
1984, but before November 25, 1986.
(e) For the purposes of this section, the annual capacity factor is
determined by dividing the actual heat input to the steam generating
unit during the calendar year from the combustion of coal, wood, or
municipal-type solid waste, and other fuels, as applicable, by the
potential heat input to the steam generating unit if the steam
generating unit had been operated for 8,760 hours at the maximum design
heat input capacity.
(f) On and after the date on which the initial performance test is
completed or is required to be completed under 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts coal, oil, wood, or mixtures of these fuels with any other
fuels shall cause to be discharged into the atmosphere any gases that
exhibit greater than 20 percent opacity (6-minute average), except for
one 6-minute period per hour of not more than 27 percent opacity.
(g) The particulate matter and opacity standards apply at all times,
except during periods of startup, shutdown or malfunction.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989;
65 FR 61752, Oct. 17, 2000]
Sec. 60.44b Standard for nitrogen oxides.
(a) Except as provided under paragraphs (k) and (l) of this section,
on and after the date on which the initial performance test is completed
or is required to be completed under Sec. 60.8 of this part, whichever
date comes first, no owner or operator of an affected facility that is
subject to the provisions of this section and that combusts only coal,
oil, or natural gas shall cause to be discharged into the atmosphere
from that affected facility any gases that contain nitrogen oxides
(expressed as NO2) in excess of the following emission
limits:
------------------------------------------------------------------------
Nitrogen oxide
emission
limits ng/J
(lb/million
Fuel/Steam generating unit type Btu)
(expressed as
NO2) heat
input
------------------------------------------------------------------------
(1) Natural gas and distillate oil, except (4):
(i) Low heat release rate............................. 43 (0.10)
(ii) High heat release rate........................... 86 (0.20)
(2) Residual oil:
(i) Low heat release rate............................. 130 (0.30)
(ii) High heat release rate........................... 170 (0.40)
(3) Coal:
(i) Mass-feed stoker.................................. 210 (0.50)
(ii) Spreader stoker and fluidized bed combustion..... 260 (0.60)
(iii) Pulverized coal................................. 300 (0.70)
(iv) Lignite, except (v).............................. 260 (0.60)
(v) Lignite mined in North Dakota, South Dakota, or 340 (0.80)
Montana and combusted in a slag tap furnace..........
(vi) Coal-derived synthetic fuels..................... 210 (0.50)
(4) Duct burner used in a combined cycle system:
(i) Natural gas and distillate oil.................... 86 (0.20)
(ii) Residual oil..................................... 170 (0.40)
------------------------------------------------------------------------
(b) Except as provided under paragraphs (k) and (l) of this section,
on and after the date on which the initial performance test is completed
or is required to be completed under Sec. 60.8 of this part, whichever
date comes first, no owner or operator of an affected facility that
simultaneously combusts mixtures of coal, oil, or natural gas shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain nitrogen oxides
[[Page 119]]
in excess of a limit determined by the use of the following formula:
En=[(ELgo Hgo)+(ELro
Hro)+(ELc Hc)]/
(Hgo+Hro+Hc)
where:
En is the nitrogen oxides emission limit (expressed as
NO2), ng/J (lb/million Btu)
ELgo is the appropriate emission limit from paragraph (a)(1)
for combustion of natural gas or distillate oil, ng/J (lb/
million Btu)
Hgo is the heat input from combustion of natural gas or
distillate oil,
ELro is the appropriate emission limit from paragraph (a)(2)
for combustion of residual oil,
Hro is the heat input from combustion of residual oil,
ELc is the appropriate emission limit from paragraph (a)(3)
for combustion of coal, and
Hc is the heat input from combustion of coal.
(c) Except as provided under paragraph (l) of this section, on and
after the date on which the initial performance test is completed or is
required to be completed under Sec. 60.8 of this part, whichever date
comes first, no owner or operator of an affected facility that
simultaneously combusts coal or oil, or a mixture of these fuels with
natural gas, and wood, municipal-type solid waste, or any other fuel
shall cause to be discharged into the atmosphere any gases that contain
nitrogen oxides in excess of the emission limit for the coal or oil, or
mixtures of these fuels with natural gas combusted in the affected
facility, as determined pursuant to paragraph (a) or (b) of this
section, unless the affected facility has an annual capacity factor for
coal or oil, or mixture of these fuels with natural gas of 10 percent
(0.10) or less and is subject to a federally enforceable requirement
that limits operation of the affected facility to an annual capacity
factor of 10 percent (0.10) or less for coal, oil, or a mixture of these
fuels with natural gas.
(d) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that simultaneously combusts natural gas with wood, municipal-type solid
waste, or other solid fuel, except coal, shall cause to be discharged
into the atmosphere from that affected facility any gases that contain
nitrogen oxides in excess of 130 ng/J (0.30 lb/million Btu) heat input
unless the affected facility has an annual capacity factor for natural
gas of 10 percent (0.10) or less and is subject to a federally
enforceable requirement that limits operation of the affected facility
to an annual capacity factor of 10 percent (0.10) or less for natural
gas.
(e) Except as provided under paragraph (l) of this section, on and
after the date on which the initial performance test is completed or is
required to be completed under Sec. 60.8 of this part, whichever date
comes first, no owner or operator of an affected facility that
simultaneously combusts coal, oil, or natural gas with byproduct/waste
shall cause to be discharged into the atmosphere any gases that contain
nitrogen oxides in excess of the emission limit determined by the
following formula unless the affected facility has an annual capacity
factor for coal, oil, and natural gas of 10 percent (0.10) or less and
is subject to a federally enforceable requirement that limits operation
of the affected facility to an annual capacity factor of 10 percent
(0.10) or less:
En=[(ELgo Hgo)+(ELro
Hro)+ (ELc Hc)]/
(Hgo+Hro+Hc)
where:
En is the nitrogen oxides emission limit (expressed as
NO2), ng/J (lb/million Btu)
ELgo is the appropriate emission limit from paragraph (a)(1)
for combustion of natural gas or distillate oil, ng/J (lb/
million Btu).
Hgo is the heat input from combustion of natural gas,
distillate oil and gaseous byproduct/waste, ng/J (lb/million
Btu).
ELro is the appropriate emission limit from paragraph (a)(2)
for combustion of residual oil, ng/J (lb/million Btu)
Hro is the heat input from combustion of residual oil and/or
liquid byproduct/waste.
ELc is the appropriate emission limit from paragraph (a)(3)
for combustion of coal, and
Hc is the heat input from combustion of coal.
(f) Any owner or operator of an affected facility that combusts
byproduct/waste with either natural gas or oil may petition the
Administrator within 180 days of the initial startup of the affected
facility to establish a nitrogen oxides emission limit which shall apply
specifically to that affected facility
[[Page 120]]
when the byproduct/waste is combusted. The petition shall include
sufficient and appropriate data, as determined by the Administrator,
such as nitrogen oxides emissions from the affected facility, waste
composition (including nitrogen content), and combustion conditions to
allow the Administrator to confirm that the affected facility is unable
to comply with the emission limits in paragraph (e) of this section and
to determine the appropriate emission limit for the affected facility.
(1) Any owner or operator of an affected facility petitioning for a
facility-specific nitrogen oxides emission limit under this section
shall:
(i) Demonstrate compliance with the emission limits for natural gas
and distillate oil in paragraph (a)(1) of this section or for residual
oil in paragraph (a)(2) of this section, as appropriate, by conducting a
30-day performance test as provided in Sec. 60.46b(e). During the
performance test only natural gas, distillate oil, or residual oil shall
be combusted in the affected facility; and
(ii) Demonstrate that the affected facility is unable to comply with
the emission limits for natural gas and distillate oil in paragraph
(a)(1) of this section or for residual oil in paragraph (a)(2) of this
section, as appropriate, when gaseous or liquid byproduct/waste is
combusted in the affected facility under the same conditions and using
the same technological system of emission reduction applied when
demonstrating compliance under paragraph (f)(1)(i) of this section.
(2) The nitrogen oxides emission limits for natural gas or
distillate oil in paragraph (a)(1) of this section or for residual oil
in paragraph (a)(2) of this section, as appropriate, shall be applicable
to the affected facility until and unless the petition is approved by
the Administrator. If the petition is approved by the Administrator, a
facility-specific nitrogen oxides emission limit will be established at
the nitrogen oxides emission level achievable when the affected facility
is combusting oil or natural gas and byproduct/waste in a manner that
the Administrator determines to be consistent with minimizing nitrogen
oxides emissions.
(g) Any owner or operator of an affected facility that combusts
hazardous waste (as defined by 40 CFR part 261 or 40 CFR part 761) with
natural gas or oil may petition the Administrator within 180 days of the
initial startup of the affected facility for a waiver from compliance
with the nitrogen oxides emission limit which applies specifically to
that affected facility. The petition must include sufficient and
appropriate data, as determined by the Administrator, on nitrogen oxides
emissions from the affected facility, waste destruction efficiencies,
waste composition (including nitrogen content), the quantity of specific
wastes to be combusted and combustion conditions to allow the
Administrator to determine if the affected facility is able to comply
with the nitrogen oxides emission limits required by this section. The
owner or operator of the affected facility shall demonstrate that when
hazardous waste is combusted in the affected facility, thermal
destruction efficiency requirements for hazardous waste specified in an
applicable federally enforceable requirement preclude compliance with
the nitrogen oxides emission limits of this section. The nitrogen oxides
emission limits for natural gas or distillate oil in paragraph (a)(1) of
this section or for residual oil in paragraph (a)(2) of this section, as
appropriate, are applicable to the affected facility until and unless
the petition is approved by the Administrator. (See 40 CFR 761.70 for
regulations applicable to the incineration of materials containing
polychlorinated biphenyls (PCB's).)
(h) For purposes of paragraph (i) of this section, the nitrogen
oxide standards under this section apply at all times including periods
of startup, shutdown, or malfunction.
(i) Except as provided under paragraph (j) of this section,
compliance with the emission limits under this section is determined on
a 30-day rolling average basis.
(j) Compliance with the emission limits under this section is
determined on a 24-hour average basis for the initial performance test
and on a 3-hour average basis for subsequent performance tests for any
affected facilities that:
[[Page 121]]
(1) Combust, alone or in combination, only natural gas, distillate
oil, or residual oil with a nitrogen content of 0.30 weight percent or
less;
(2) Have a combined annual capacity factor of 10 percent or less for
natural gas, distillate oil, and residual oil with a nitrogen content of
0.30 weight percent or less; and
(3) Are subject to a Federally enforceable requirement limiting
operation of the affected facility to the firing of natural gas,
distillate oil, and/or residual oil with a nitrogen content of 0.30
weight percent or less and limiting operation of the affected facility
to a combined annual capacity factor of 10 percent or less for natural
gas, distillate oil, and residual oil and a nitrogen content of 0.30
weight percent or less.
(k) Affected facilities that meet the criteria described in
paragraphs (j) (1), (2), and (3) of this section, and that have a heat
input capacity of 73 MW (250 million Btu/hour) or less, are not subject
to the nitrogen oxides emission limits under this section.
(l) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
which commenced construction, modification, or reconstruction after July
9, 1997 shall cause to be discharged into the atmosphere from that
affected facility any gases that contain nitrogen oxides (expressed as
NO2) in excess of the following limits:
(1) If the affected facility combusts coal, oil, or natural gas, or
a mixture of these fuels, or with any other fuels: A limit of 86 ng/
JI (0.20 lb/million Btu) heat input unless the affected
facility has an annual capacity factor for coal, oil, and natural gas of
10 percent (0.10) or less and is subject to a federally enforceable
requirement that limits operation of the facility to an annual capacity
factor of 10 percent (0.10) or less for coal, oil, and natural gas; or
(2) If the affected facility has a low heat release rate and
combusts natural gas or distillate oil in excess of 30 percent of the
heat input from the combustion of all fuels, a limit determined by use
of the following formula:
En = [(0.10 * Hgo)+(0.20 * Hr)]/
(Hgo+Hr)
Where:
En is the NOX emission limit, (lb/million Btu),
Hgo is the heat input from combustion of natural gas or
distillate oil, and
Hr is the heat input from combustion of any other fuel.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51825, Dec. 18, 1989;
63 FR 49454, Sept. 16, 1998]
Sec. 60.45b Compliance and performance test methods and procedures for sulfur dioxide.
(a) The sulfur dioxide emission standards under Sec. 60.42b apply at
all times.
(b) In conducting the performance tests required under Sec. 60.8,
the owner or operator shall use the methods and procedures in appendix A
of this part or the methods and procedures as specified in this section,
except as provided in Sec. 60.8(b). Section 60.8(f) does not apply to
this section. The 30-day notice required in Sec. 60.8(d) applies only to
the initial performance test unless otherwise specified by the
Administrator.
(c) The owner or operator of an affected facility shall conduct
performance tests to determine compliance with the percent of potential
sulfur dioxide emission rate (% Ps) and the sulfur dioxide
emission rate (Es) pursuant to Sec. 60.42b following the
procedures listed below, except as provided under paragraph (d) of this
section.
(1) The initial performance test shall be conducted over the first
30 consecutive operating days of the steam generating unit. Compliance
with the sulfur dioxide standards shall be determined using a 30-day
average. The first operating day included in the initial performance
test shall be scheduled within 30 days after achieving the maximum
production rate at which the affected facility will be operated, but not
later than 180 days after initial startup of the facility.
(2) If only coal or only oil is combusted, the following procedures
are used:
(i) The procedures in Method 19 are used to determine the hourly
sulfur dioxide emission rate (Eho) and the 30-day average
emission rate (Eao). The hourly averages used to compute the
30-day
[[Page 122]]
averages are obtained from the continuous emission monitoring system of
Sec. 60.47b (a) or (b).
(ii) The percent of potential sulfur dioxide emission rate (%
Ps) emitted to the atmosphere is computed using the following
formula:
% Ps=100 (1-% Rg/100)(1-% Rf/100)
where:
% Rg is the sulfur dioxide removal efficiency of the control
device as determined by Method 19, in percent.
% Rf is the sulfur dioxide removal efficiency of fuel
pretreatment as determined by Method 19, in percent.
(3) If coal or oil is combusted with other fuels, the same
procedures required in paragraph (c)(2) of this section are used, except
as provided in the following:
(i) An adjusted hourly sulfur dioxide emission rate
(Ehoo) is used in Equation 19-19 of Method 19 to
compute an adjusted 30-day average emission rate
(Eaoo). The Eho is computed using the
following formula:
Ehoo=[Eho-Ew(1-Xk)
]/Xk
where:
Ehoo is the adjusted hourly sulfur dioxide
emission rate, ng/J (lb/million Btu).
Eho is the hourly sulfur dioxide emission rate, ng/J (lb/
million Btu).
Ew is the sulfur dioxide concentration in fuels other than
coal and oil combusted in the affected facility, as determined
by the fuel sampling and analysis procedures in Method 19, ng/
J (lb/million Btu). The value Ew for each fuel lot
is used for each hourly average during the time that the lot
is being combusted.
Xk is the fraction of total heat input from fuel combustion
derived from coal, oil, or coal and oil, as determined by
applicable procedures in Method 19.
(ii) To compute the percent of potential sulfur dioxide emission
rate (% Ps), an adjusted % Rg (%
Rgo) is computed from the adjusted
Eaoo from paragraph (b)(3)(i) of this section and
an adjusted average sulfur dioxide inlet rate
(Eaio) using the following formula:
% Rgo=100 (1.0-Eaoo/
Eaio)
To compute Eaio, an adjusted hourly sulfur dioxide
inlet rate (Ehio) is used. The
Ehio is computed using the following formula:
Ehio=[Ehi-Ew(1-Xk)
]/Xk
where:
Ehio is the adjusted hourly sulfur dioxide inlet
rate, ng/J (lb/million Btu).
Ehi is the hourly sulfur dioxide inlet rate, ng/J (lb/million
Btu).
(4) The owner or operator of an affected facility subject to
paragraph (b)(3) of this section does not have to measure parameters
Ew or Xk if the owner or operator elects to assume
that Xk=1.0. Owners or operators of affected facilities who
assume Xk=1.0 shall
(i) Determine % Ps following the procedures in paragraph
(c)(2) of this section, and
(ii) Sulfur dioxide emissions (Es) are considered to be
in compliance with sulfur dioxide emission limits under Sec. 60.42b.
(5) The owner or operator of an affected facility that qualifies
under the provisions of Sec. 60.42b(d) does not have to measure
parameters Ew or Xk under paragraph (b)(3) of this
section if the owner or operator of the affected facility elects to
measure sulfur dioxide emission rates of the coal or oil following the
fuel sampling and analysis procedures under Method 19.
(d) Except as provided in paragraph (j), the owner or operator of an
affected facility that combusts only very low sulfur oil, has an annual
capacity factor for oil of 10 percent (0.10) or less, and is subject to
a Federally enforceable requirement limiting operation of the affected
facility to an annual capacity factor for oil of 10 percent (0.10) or
less shall:
(1) Conduct the initial performance test over 24 consecutive steam
generating unit operating hours at full load;
(2) Determine compliance with the standards after the initial
performance test based on the arithmetic average of the hourly emissions
data during each steam generating unit operating day if a continuous
emission measurement system (CEMS) is used, or based on a daily average
if Method 6B or fuel sampling and analysis procedures under Method 19
are used.
(e) The owner or operator of an affected facility subject to
Sec. 60.42b(d)(1) shall demonstrate the maximum design capacity of the
steam generating unit by operating the facility at maximum capacity for
24 hours. This demonstration will be made during the initial
[[Page 123]]
performance test and a subsequent demonstration may be requested at any
other time. If the 24-hour average firing rate for the affected facility
is less than the maximum design capacity provided by the manufacturer of
the affected facility, the 24-hour average firing rate shall be used to
determine the capacity utilization rate for the affected facility,
otherwise the maximum design capacity provided by the manufacturer is
used.
(f) For the initial performance test required under Sec. 60.8,
compliance with the sulfur dioxide emission limits and percent reduction
requirements under Sec. 60.42b is based on the average emission rates
and the average percent reduction for sulfur dioxide for the first 30
consecutive steam generating unit operating days, except as provided
under paragraph (d) of this section. The initial performance test is the
only test for which at least 30 days prior notice is required unless
otherwise specified by the Administrator. The initial performance test
is to be scheduled so that the first steam generating unit operating day
of the 30 successive steam generating unit operating days is completed
within 30 days after achieving the maximum production rate at which the
affected facility will be operated, but not later than 180 days after
initial startup of the facility. The boiler load during the 30-day
period does not have to be the maximum design load, but must be
representative of future operating conditions and include at least one
24-hour period at full load.
(g) After the initial performance test required under Sec. 60.8,
compliance with the sulfur dioxide emission limits and percent reduction
requirements under Sec. 60.42b is based on the average emission rates
and the average percent reduction for sulfur dioxide for 30 successive
steam generating unit operating days, except as provided under paragraph
(d). A separate performance test is completed at the end of each steam
generating unit operating day after the initial performance test, and a
new 30-day average emission rate and percent reduction for sulfur
dioxide are calculated to show compliance with the standard.
(h) Except as provided under paragraph (i) of this section, the
owner or operator of an affected facility shall use all valid sulfur
dioxide emissions data in calculating % Ps and Eho
under paragraph (c), of this section whether or not the minimum
emissions data requirements under Sec. 60.46b are achieved. All valid
emissions data, including valid sulfur dioxides emission data collected
during periods of startup, shutdown and malfunction, shall be used in
calculating % Ps and Eho pursuant to paragraph (c)
of this section.
(i) During periods of malfunction or maintenance of the sulfur
dioxide control systems when oil is combusted as provided under
Sec. 60.42b(i), emission data are not used to calculate % Ps
or Es under Sec. 60.42b (a), (b) or (c), however, the
emissions data are used to determine compliance with the emission limit
under Sec. 60.42b(i).
(j) The owner or operator of an affected facility that combusts very
low sulfur oil is not subject to the compliance and performance testing
requirements of this section if the owner or operator obtains fuel
receipts as described in Sec. 60.49b(r).
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18,
1989]
Sec. 60.46b Compliance and performance test methods and procedures for particulate matter and nitrogen oxides.
(a) The particulate matter emission standards and opacity limits
under Sec. 60.43b apply at all times except during periods of startup,
shutdown, or malfunction. The nitrogen oxides emission standards under
Sec. 60.44b apply at all times.
(b) Compliance with the particulate matter emission standards under
Sec. 60.43b shall be determined through performance testing as described
in paragraph (d) of this section.
(c) Compliance with the nitrogen oxides emission standards under
Sec. 60.44b shall be determined through performance testing under
paragraph (e) or (f), or under paragraphs (g) and (h) of this section,
as applicable.
(d) To determine compliance with the particulate matter emission
limits and opacity limits under Sec. 60.43b, the owner or operator of an
affected facility shall
[[Page 124]]
conduct an initial performance test as required under Sec. 60.8 using
the following procedures and reference methods:
(1) Method 3B is used for gas analysis when applying Method 5 or
Method 17.
(2) Method 5, Method 5B, or Method 17 shall be used to measure the
concentration of particulate matter as follows:
(i) Method 5 shall be used at affected facilities without wet flue
gas desulfurization (FGD) systems; and
(ii) Method 17 may be used at facilities with or without wet
scrubber systems provided the stack gas temperature does not exceed a
temperature of 160 deg.C (320 deg.F). The procedures of sections 2.1
and 2.3 of Method 5B may be used in Method 17 only if it is used after a
wet FGD system. Do not use Method 17 after wet FGD systems if the
effluent is saturated or laden with water droplets.
(iii) Method 5B is to be used only after wet FGD systems.
(3) Method 1 is used to select the sampling site and the number of
traverse sampling points. The sampling time for each run is at least 120
minutes and the minimum sampling volume is 1.7 dscm (60 dscf) except
that smaller sampling times or volumes may be approved by the
Administrator when necessitated by process variables or other factors.
(4) For Method 5, the temperature of the sample gas in the probe and
filter holder is monitored and is maintained at 16014 deg.C
(32025 deg.F).
(5) For determination of particulate matter emissions, the oxygen or
carbon dioxide sample is obtained simultaneously with each run of Method
5, Method 5B or Method 17 by traversing the duct at the same sampling
location.
(6) For each run using Method 5, Method 5B or Method 17, the
emission rate expressed in nanograms per joule heat input is determined
using:
(i) The oxygen or carbon dioxide measurements and particulate matter
measurements obtained under this section,
(ii) The dry basis F factor, and
(iii) The dry basis emission rate calculation procedure contained in
Method 19.
(7) Method 9 is used for determining the opacity of stack emissions.
(e) To determine compliance with the emission limits for nitrogen
oxides required under Sec. 60.44b, the owner or operator of an affected
facility shall conduct the performance test as required under Sec. 60.8
using the continuous system for monitoring nitrogen oxides under
Sec. 60.48(b).
(1) For the initial compliance test, nitrogen oxides from the steam
generating unit are monitored for 30 successive steam generating unit
operating days and the 30-day average emission rate is used to determine
compliance with the nitrogen oxides emission standards under
Sec. 60.44b. The 30-day average emission rate is calculated as the
average of all hourly emissions data recorded by the monitoring system
during the 30-day test period.
(2) Following the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, the owner or operator of an affected
facility which combusts coal or which combusts residual oil having a
nitrogen content greater than 0.30 weight percent shall determine
compliance with the nitrogen oxides emission standards under Sec. 60.44b
on a continuous basis through the use of a 30-day rolling average
emission rate. A new 30-day rolling average emission rate is calculated
each steam generating unit operating day as the average of all of the
hourly nitrogen oxides emission data for the preceding 30 steam
generating unit operating days.
(3) Following the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of this part,
whichever date comes first, the owner or operator of an affected
facility which has a heat input capacity greater than 73 MW (250 million
Btu/hour) and which combusts natural gas, distillate oil, or residual
oil having a nitrogen content of 0.30 weight percent or less shall
determine compliance with the nitrogen oxides standards under
Sec. 60.44b on a continuous basis through the use of a 30-day rolling
average emission rate. A new 30-day rolling average emission rate is
calculated each steam generating unit operating day as the average of
all of
[[Page 125]]
the hourly nitrogen oxides emission data for the preceding 30 steam
generating unit operating days.
(4) Following the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, the owner or operator of an affected
facility which has a heat input capacity of 73 MW (250 million Btu/hour)
or less and which combusts natural gas, distillate oil, or residual oil
having a nitrogen content of 0.30 weight percent or less shall upon
request determine compliance with the nitrogen oxides standards under
Sec. 60.44b through the use of a 30-day performance test. During periods
when performance tests are not requested, nitrogen oxides emissions data
collected pursuant to Sec. 60.48b(g)(1) or Sec. 60.48b(g)(2) are used to
calculate a 30-day rolling average emission rate on a daily basis and
used to prepare excess emission reports, but will not be used to
determine compliance with the nitrogen oxides emission standards. A new
30-day rolling average emission rate is calculated each steam generating
unit operating day as the average of all of the hourly nitrogen oxides
emission data for the preceding 30 steam generating unit operating days.
(5) If the owner or operator of an affected facility which combusts
residual oil does not sample and analyze the residual oil for nitrogen
content, as specified in Sec. 60.49b(e), the requirements of paragraph
(iii) of this section apply and the provisions of paragraph (iv) of this
section are inapplicable.
(f) To determine compliance with the emissions limits for
NOX required by Sec. 60.44b(a)(4) or Sec. 60.44b(l) for duct
burners used in combined cycle systems, either of the procedures
described in paragraph (f)(1) or (2) of this section may be used:
(1) The owner or operator of an affected facility shall conduct the
performance test required under Sec. 60.8 as follows:
(i) The emissions rate (E) of NOX shall be computed using
Equation of 1 this section:
E = Esg + (Hg /Hb)(Esg - Eg) (Eq. 1)
Where:
E = emissions rate of NOX from the duct burner, ng/J (lb/
million Btu) heat input
Esg = combined effluent emissions rate, in ng/J (lb/million Btu) heat
input using appropriate F-Factor as described in Method 19
Hg = heat input rate to the combustion turbine, in Joules/hour (million
Btu/hour)
Hb = heat input rate to the duct burner, in Joules/hour (million Btu/
hour)
Eg = emissions rate from the combustion turbine, in ng/J (lb/million
Btu) heat input calculated using appropriate F-Factor as
described in Method 19
(ii) Method 7E of appendix A of this part shall be used to determine
the NOX concentrations. Method 3A or 3B of appendix A of this
part shall be used to determine oxygen concentration.
(iii) The owner or operator shall identify and demonstrate to the
Administrator's satisfaction suitable methods to determine the average
hourly heat input rate to the combustion turbine and the average hourly
heat input rate to the affected duct burner.
(iv) Compliance with the emissions limits under Sec. 60.44b (a)(4)
or Sec. 60.44b(l) is determined by the three-run average (nominal 1-hour
runs) for the initial and subsequent performance tests; or
(2) The owner or operator of an affected facility may elect to
determine compliance on a 30-day rolling average basis by using the
continuous emission monitoring system specified under Sec. 60.48b for
measuring NOX and oxygen and meet the requirements of
Sec. 60.48b. The sampling site shall be located at the outlet from the
steam generating unit. The NOX emissions rate at the outlet
from the steam generating unit shall constitute the NOX
emissions rate from the duct burner of the combined cycle system.
(g) The owner or operator of an affected facility described in
Sec. 60.44b(j) or Sec. 60.44b(k) shall demonstrate the maximum heat
input capacity of the steam generating unit by operating the facility at
maximum capacity for 24 hours. The owner or operator of an affected
facility shall determine the maximum heat input capacity using the heat
loss method described in sections 5 and 7.3 of the ASME Power Test Codes
4.1 (see IBR Sec. 60.17(h)). This demonstration of maximum heat input
capacity shall be made during the initial performance test for affected
facilities that meet the criteria of Sec. 60.44b(j). It shall be made
within 60 days after achieving
[[Page 126]]
the maximum production rate at which the affected facility will be
operated, but not later than 180 days after initial start-up of each
facility, for affected facilities meeting the criteria of
Sec. 60.44b(k). Subsequent demonstrations may be required by the
Administrator at any other time. If this demonstration indicates that
the maximum heat input capacity of the affected facility is less than
that stated by the manufacturer of the affected facility, the maximum
heat input capacity determined during this demonstration shall be used
to determine the capacity utilization rate for the affected facility.
Otherwise, the maximum heat input capacity provided by the manufacturer
is used.
(h) The owner or operator of an affected facility described in
Sec. 60.44b(j) that has a heat input capacity greater than 73 MW (250
million Btu/hour) shall:
(1) Conduct an initial performance test as required under Sec. 60.8
over a minimum of 24 consecutive steam generating unit operating hours
at maximum heat input capacity to demonstrate compliance with the
nitrogen oxides emission standards under Sec. 60.44b using Method 7, 7A,
7E, or other approved reference methods; and
(2) Conduct subsequent performance tests once per calendar year or
every 400 hours of operation (whichever comes first) to demonstrate
compliance with the nitrogen oxides emission standards under Sec. 60.44b
over a minimum of 3 consecutive steam generating unit operating hours at
maximum heat input capacity using Method 7, 7A, 7E, or other approved
reference methods.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18,
1989; 55 FR 18876, May 7, 1990; 65 FR 61752, Oct. 17, 2000; 66 FR 18553,
Apr. 10, 2001]
Sec. 60.47b Emission monitoring for sulfur dioxide.
(a) Except as provided in paragraphs (b) and (f) of this section,
the owner or operator of an affected facility subject to the sulfur
dioxide standards under Sec. 60.42b shall install, calibrate, maintain,
and operate continuous emission monitoring systems (CEMS) for measuring
sulfur dioxide concentrations and either oxygen (O2) or
carbon dioxide (CO2) concentrations and shall record the
output of the systems. The sulfur dioxide and either oxygen or carbon
dioxide concentrations shall both be monitored at the inlet and outlet
of the sulfur dioxide control device.
(b) As an alternative to operating CEMS as required under paragraph
(a) of this section, an owner or operator may elect to determine the
average sulfur dioxide emissions and percent reduction by:
(1) Collecting coal or oil samples in an as-fired condition at the
inlet to the steam generating unit and analyzing them for sulfur and
heat content according to Method 19. Method 19 provides procedures for
converting these measurements into the format to be used in calculating
the average sulfur dioxide input rate, or
(2) Measuring sulfur dioxide according to Method 6B at the inlet or
outlet to the sulfur dioxide control system. An initial stratification
test is required to verify the adequacy of the Method 6B sampling
location. The stratification test shall consist of three paired runs of
a suitable sulfur dioxide and carbon dioxide measurement train operated
at the candidate location and a second similar train operated according
to the procedures in section 3.2 and the applicable procedures in
section 7 of Performance Specification 2. Method 6B, Method 6A, or a
combination of Methods 6 and 3 or 3B or Methods 6C and 3A are suitable
measurement techniques. If Method 6B is used for the second train,
sampling time and timer operation may be adjusted for the stratification
test as long as an adequate sample volume is collected; however, both
sampling trains are to be operated similarly. For the location to be
adequate for Method 6B 24-hour tests, the mean of the absolute
difference between the three paired runs must be less than 10 percent.
(3) A daily sulfur dioxide emission rate, ED, shall be
determined using the procedure described in Method 6A, section 7.6.2
(Equation 6A-8) and stated in ng/J (lb/million Btu) heat input.
(4) The mean 30-day emission rate is calculated using the daily
measured values in ng/J (lb/million Btu) for 30
[[Page 127]]
successive steam generating unit operating days using equation 19-20 of
Method 19.
(c) The owner or operator of an affected facility shall obtain
emission data for at least 75 percent of the operating hours in at least
22 out of 30 successive boiler operating days. If this minimum data
requirement is not met with a single monitoring system, the owner or
operator of the affected facility shall supplement the emission data
with data collected with other monitoring systems as approved by the
Administrator or the reference methods and procedures as described in
paragraph (b) of this section.
(d) The 1-hour average sulfur dioxide emission rates measured by the
CEMS required by paragraph (a) of this section and required under
Sec. 60.13(h) is expressed in ng/J or lb/million Btu heat input and is
used to calculate the average emission rates under Sec. 60.42b. Each 1-
hour average sulfur dioxide emission rate must be based on more than 30
minutes of steam generating unit operation and include at least 2 data
points with each representing a 15-minute period. Hourly sulfur dioxide
emission rates are not calculated if the affected facility is operated
less than 30 minutes in a 1-hour period and are not counted toward
determination of a steam generating unit operating day.
(e) The procedures under Sec. 60.13 shall be followed for
installation, evaluation, and operation of the CEMS.
(1) All CEMS shall be operated in accordance with the applicable
procedures under Performance Specifications 1, 2, and 3 (appendix B).
(2) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with Procedure 1 (appendix F).
(3) For affected facilities combusting coal or oil, alone or in
combination with other fuels, the span value of the sulfur dioxide CEMS
at the inlet to the sulfur dioxide control device is 125 percent of the
maximum estimated hourly potential sulfur dioxide emissions of the fuel
combusted, and the span value of the CEMS at the outlet to the sulfur
dioxide control device is 50 percent of the maximum estimated hourly
potential sulfur dioxide emissions of the fuel combusted.
(f) The owner or operator of an affected facility that combusts very
low sulfur oil is not subject to the emission monitoring requirements of
this section if the owner or operator obtains fuel receipts as described
in Sec. 60.49b(r).
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, Dec. 18, 1989;
55 FR 5212, Feb. 14, 1990; 55 FR 18876, May 7, 1990]
Sec. 60.48b Emission monitoring for particulate matter and nitrogen oxides.
(a) The owner or operator of an affected facility subject to the
opacity standard under Sec. 60.43b shall install, calibrate, maintain,
and operate a continuous monitoring system for measuring the opacity of
emissions discharged to the atmosphere and record the output of the
system.
(b) Except as provided under paragraphs (g), (h), and (i) of this
section, the owner or operator of an affected facility shall comply with
either paragraphs (b)(1) or (b)(2) of this section.
(1) Install, calibrate, maintain, and operate a continuous
monitoring system, and record the output of the system, for measuring
nitrogen oxides emissions discharged to the atmosphere; or
(2) If the owner or operator has installed a nitrogen oxides
emission rate continuous emission monitoring system (CEMS) to meet the
requirements of part 75 of this chapter and is continuing to meet the
ongoing requirements of part 75 of this chapter, that CEMS may be used
to meet the requirements of this section, except that the owner or
operator shall also meet the requirements of Sec. 60.49b. Data reported
to meet the requirements of Sec. 60.49b shall not include data
substituted using the missing data procedures in subpart D of part 75 of
this chapter, nor shall the data have been bias adjusted according to
the procedures of part 75 of this chapter.
(c) The continuous monitoring systems required under paragraph (b)
of this section shall be operated and data recorded during all periods
of operation of the affected facility except for continuous monitoring
system breakdowns and repairs. Data is recorded during calibration
checks, and zero and span adjustments.
[[Page 128]]
(d) The 1-hour average nitrogen oxides emission rates measured by
the continuous nitrogen oxides monitor required by paragraph (b) of this
section and required under Sec. 60.13(h) shall be expressed in ng/J or
lb/million Btu heat input and shall be used to calculate the average
emission rates under Sec. 60.44b. The 1-hour averages shall be
calculated using the data points required under Sec. 60.13(b). At least
2 data points must be used to calculate each 1-hour average.
(e) The procedures under Sec. 60.13 shall be followed for
installation, evaluation, and operation of the continuous monitoring
systems.
(1) For affected facilities combusting coal, wood or municipal-type
solid waste, the span value for a continuous monitoring system for
measuring opacity shall be between 60 and 80 percent.
(2) For affected facilities combusting coal, oil, or natural gas,
the span value for nitrogen oxides is determined as follows:
------------------------------------------------------------------------
Span values for
Fuel nitrogen oxides
(PPM)
------------------------------------------------------------------------
Natural gas.......................................... 500
Oil.................................................. 500
Coal................................................. 1,000
Mixtures............................................. 500(x+y)+1,000z
------------------------------------------------------------------------
where:
x is the fraction of total heat input derived from natural gas,
y is the fraction of total heat input derived from oil, and
z is the fraction of total heat input derived from coal.
(3) All span values computed under paragraph (e)(2) of this section
for combusting mixtures of regulated fuels are rounded to the nearest
500 ppm.
(f) When nitrogen oxides emission data are not obtained because of
continuous monitoring system breakdowns, repairs, calibration checks and
zero and span adjustments, emission data will be obtained by using
standby monitoring systems, Method 7, Method 7A, or other approved
reference methods to provide emission data for a minimum of 75 percent
of the operating hours in each steam generating unit operating day, in
at least 22 out of 30 successive steam generating unit operating days.
(g) The owner or operator of an affected facility that has a heat
input capacity of 73 MW (250 million Btu/hour) or less, and which has an
annual capacity factor for residual oil having a nitrogen content of
0.30 weight percent or less, natural gas, distillate oil, or any mixture
of these fuels, greater than 10 percent (0.10) shall:
(1) Comply with the provisions of paragraphs (b), (c), (d), (e)(2),
(e)(3), and (f) of this section, or
(2) Monitor steam generating unit operating conditions and predict
nitrogen oxides emission rates as specified in a plan submitted pursuant
to Sec. 60.49b(c).
(h) The owner or operator of a duct burner, as described in
Sec. 60.41b, which is subject to the NOX standards of
Sec. 60.44b(a)(4) or Sec. 60.44b(l) is not required to install or
operate a continuous emissions monitoring system to measure
NOX emissions.
(i) The owner or operator of an affected facility described in
Sec. 60.44b(j) or Sec. 60.44b(k) is not required to install or operate a
continuous monitoring system for measuring nitrogen oxides emissions.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51825, Dec. 18, 1989;
63 FR 49455, Sept. 16, 1998; 66 FR 18553, Apr. 10, 2001]
Sec. 60.49b Reporting and recordkeeping requirements.
(a) The owner or operator of each affected facility shall submit
notification of the date of initial startup, as provided by Sec. 60.7.
This notification shall include:
(1) The design heat input capacity of the affected facility and
identification of the fuels to be combusted in the affected facility,
(2) If applicable, a copy of any Federally enforceable requirement
that limits the annual capacity factor for any fuel or mixture of fuels
under Secs. 60.42b(d)(1), 60.43b(a)(2), (a)(3)(iii), (c)(2)(ii),
(d)(2)(iii), 60.44b(c), (d), (e), (i), (j), (k), 60.45b(d), (g),
60.46b(h), or 60.48b(i),
(3) The annual capacity factor at which the owner or operator
anticipates operating the facility based on all fuels fired and based on
each individual fuel fired, and,
(4) Notification that an emerging technology will be used for
controlling
[[Page 129]]
emissions of sulfur dioxide. The Administrator will examine the
description of the emerging technology and will determine whether the
technology qualifies as an emerging technology. In making this
determination, the Administrator may require the owner or operator of
the affected facility to submit additional information concerning the
control device. The affected facility is subject to the provisions of
Sec. 60.42b(a) unless and until this determination is made by the
Administrator.
(b) The owner or operator of each affected facility subject to the
sulfur dioxide, particulate matter, and/or nitrogen oxides emission
limits under Secs. 60.42b, 60.43b, and 60.44b shall submit to the
Administrator the performance test data from the initial performance
test and the performance evaluation of the CEMS using the applicable
performance specifications in appendix B. The owner or operator of each
affected facility described in Sec. 60.44b(j) or Sec. 60.44b(k) shall
submit to the Administrator the maximum heat input capacity data from
the demonstration of the maximum heat input capacity of the affected
facility.
(c) The owner or operator of each affected facility subject to the
nitrogen oxides standard of Sec. 60.44b who seeks to demonstrate
compliance with those standards through the monitoring of steam
generating unit operating conditions under the provisions of
Sec. 60.48b(g)(2) shall submit to the Administrator for approval a plan
that identifies the operating conditions to be monitored under
Sec. 60.48b(g)(2) and the records to be maintained under Sec. 60.49b(j).
This plan shall be submitted to the Administrator for approval within
360 days of the initial startup of the affected facility. The plan
shall:
(1) Identify the specific operating conditions to be monitored and
the relationship between these operating conditions and nitrogen oxides
emission rates (i.e., ng/J or lbs/million Btu heat input). Steam
generating unit operating conditions include, but are not limited to,
the degree of staged combustion (i.e., the ratio of primary air to
secondary and/or tertiary air) and the level of excess air (i.e., flue
gas oxygen level);
(2) Include the data and information that the owner or operator used
to identify the relationship between nitrogen oxides emission rates and
these operating conditions;
(3) Identify how these operating conditions, including steam
generating unit load, will be monitored under Sec. 60.48b(g) on an
hourly basis by the owner or operator during the period of operation of
the affected facility; the quality assurance procedures or practices
that will be employed to ensure that the data generated by monitoring
these operating conditions will be representative and accurate; and the
type and format of the records of these operating conditions, including
steam generating unit load, that will be maintained by the owner or
operator under Sec. 60.49b(j).
If the plan is approved, the owner or operator shall maintain records of
predicted nitrogen oxide emission rates and the monitored operating
conditions, including steam generating unit load, identified in the
plan.
(d) The owner or operator of an affected facility shall record and
maintain records of the amounts of each fuel combusted during each day
and calculate the annual capacity factor individually for coal,
distillate oil, residual oil, natural gas, wood, and municipal-type
solid waste for the reporting period. The annual capacity factor is
determined on a 12-month rolling average basis with a new annual
capacity factor calculated at the end of each calendar month.
(e) For an affected facility that combusts residual oil and meets
the criteria under Secs. 60.46b(e)(4), 60.44b (j), or (k), the owner or
operator shall maintain records of the nitrogen content of the residual
oil combusted in the affected facility and calculate the average fuel
nitrogen content for the reporting period. The nitrogen content shall be
determined using ASTM Method D3431-80, Test Method for Trace Nitrogen in
Liquid Petroleum Hydrocarbons (IBR-see Sec. 60.17), or fuel suppliers.
If residual oil blends are being combusted, fuel nitrogen specifications
may be prorated based on the ratio of residual oils of different
nitrogen content in the fuel blend.
[[Page 130]]
(f) For facilities subject to the opacity standard under
Sec. 60.43b, the owner or operator shall maintain records of opacity.
(g) Except as provided under paragraph (p) of this section, the
owner or operator of an affected facility subject to the nitrogen oxides
standards under Sec. 60.44b shall maintain records of the following
information for each steam generating unit operating day:
(1) Calendar date.
(2) The average hourly nitrogen oxides emission rates (expressed as
NO2) (ng/J or lb/million Btu heat input) measured or
predicted.
(3) The 30-day average nitrogen oxides emission rates (ng/J or lb/
million Btu heat input) calculated at the end of each steam generating
unit operating day from the measured or predicted hourly nitrogen oxide
emission rates for the preceding 30 steam generating unit operating
days.
(4) Identification of the steam generating unit operating days when
the calculated 30-day average nitrogen oxides emission rates are in
excess of the nitrogen oxides emissions standards under Sec. 60.44b,
with the reasons for such excess emissions as well as a description of
corrective actions taken.
(5) Identification of the steam generating unit operating days for
which pollutant data have not been obtained, including reasons for not
obtaining sufficient data and a description of corrective actions taken.
(6) Identification of the times when emission data have been
excluded from the calculation of average emission rates and the reasons
for excluding data.
(7) Identification of ``F'' factor used for calculations, method of
determination, and type of fuel combusted.
(8) Identification of the times when the pollutant concentration
exceeded full span of the continuous monitoring system.
(9) Description of any modifications to the continuous monitoring
system that could affect the ability of the continuous monitoring system
to comply with Performance Specification 2 or 3.
(10) Results of daily CEMS drift tests and quarterly accuracy
assessments as required under appendix F, Procedure 1.
(h) The owner or operator of any affected facility in any category
listed in paragraphs (h) (1) or (2) of this section is required to
submit excess emission reports for any excess emissions which occurred
during the reporting period.
(1) Any affected facility subject to the opacity standards under
Sec. 60.43b(e) or to the operating parameter monitoring requirements
under Sec. 60.13(i)(1).
(2) Any affected facility that is subject to the nitrogen oxides
standard of Sec. 60.44b, and that
(i) Combusts natural gas, distillate oil, or residual oil with a
nitrogen content of 0.3 weight percent or less, or
(ii) Has a heat input capacity of 73 MW (250 million Btu/hour) or
less and is required to monitor nitrogen oxides emissions on a
continuous basis under Sec. 60.48b(g)(1) or steam generating unit
operating conditions under Sec. 60.48b(g)(2).
(3) For the purpose of Sec. 60.43b, excess emissions are defined as
all 6-minute periods during which the average opacity exceeds the
opacity standards under Sec. 60.43b(f).
(4) For purposes of Sec. 60.48b(g)(1), excess emissions are defined
as any calculated 30-day rolling average nitrogen oxides emission rate,
as determined under Sec. 60.46b(e), which exceeds the applicable
emission limits in Sec. 60.44b.
(i) The owner or operator of any affected facility subject to the
continuous monitoring requirements for nitrogen oxides under
Sec. 60.48(b) shall submit reports containing the information recorded
under paragraph (g) of this section.
(j) The owner or operator of any affected facility subject to the
sulfur dioxide standards under Sec. 60.42b shall submit reports.
(k) For each affected facility subject to the compliance and
performance testing requirements of Sec. 60.45b and the reporting
requirement in paragraph (j) of this section, the following information
shall be reported to the Administrator:
(1) Calendar dates covered in the reporting period.
(2) Each 30-day average sulfur dioxide emission rate (ng/J or 1b/
million Btu heat input) measured during the reporting period, ending
with the last 30-day period; reasons for noncompliance
[[Page 131]]
with the emission standards; and a description of corrective actions
taken.
(3) Each 30-day average percent reduction in sulfur dioxide
emissions calculated during the reporting period, ending with the last
30-day period; reasons for noncompliance with the emission standards;
and a description of corrective actions taken.
(4) Identification of the steam generating unit operating days that
coal or oil was combusted and for which sulfur dioxide or diluent
(oxygen or carbon dioxide) data have not been obtained by an approved
method for at least 75 percent of the operating hours in the steam
generating unit operating day; justification for not obtaining
sufficient data; and description of corrective action taken.
(5) Identification of the times when emissions data have been
excluded from the calculation of average emission rates; justification
for excluding data; and description of corrective action taken if data
have been excluded for periods other than those during which coal or oil
were not combusted in the steam generating unit.
(6) Identification of ``F'' factor used for calculations, method of
determination, and type of fuel combusted.
(7) Identification of times when hourly averages have been obtained
based on manual sampling methods.
(8) Identification of the times when the pollutant concentration
exceeded full span of the CEMS.
(9) Description of any modifications to the CEMS that could affect
the ability of the CEMS to comply with Performance Specification 2 or 3.
(10) Results of daily CEMS drift tests and quarterly accuracy
assessments as required under appendix F, Procedure 1.
(11) The annual capacity factor of each fired as provided under
paragraph (d) of this section.
(l) For each affected facility subject to the compliance and
performance testing requirements of Sec. 60.45b(d) and the reporting
requirements of paragraph (j) of this section, the following information
shall be reported to the Administrator:
(1) Calendar dates when the facility was in operation during the
reporting period;
(2) The 24-hour average sulfur dioxide emission rate measured for
each steam generating unit operating day during the reporting period
that coal or oil was combusted, ending in the last 24-hour period in the
quarter; reasons for noncompliance with the emission standards; and a
description of corrective actions taken;
(3) Identification of the steam generating unit operating days that
coal or oil was combusted for which sulfur dioxide or diluent (oxygen or
carbon dioxide) data have not been obtained by an approved method for at
least 75 percent of the operating hours; justification for not obtaining
sufficient data; and description of corrective action taken.
(4) Identification of the times when emissions data have been
excluded from the calculation of average emission rates; justification
for excluding data; and description of corrective action taken if data
have been excluded for periods other than those during which coal or oil
were not combusted in the steam generating unit.
(5) Identification of ``F'' factor used for calculations, method of
determination, and type of fuel combusted.
(6) Identification of times when hourly averages have been obtained
based on manual sampling methods.
(7) Identification of the times when the pollutant concentration
exceeded full span of the CEMS.
(8) Description of any modifications to the CEMS which could affect
the ability of the CEMS to comply with Performance Specification 2 or 3.
(9) Results of daily CEMS drift tests and quarterly accuracy
assessments as required under appendix F, Procedure 1.
(m) For each affected facility subject to the sulfur dioxide
standards under Sec. 60.42(b) for which the minimum amount of data
required under Sec. 60.47b(f) were not obtained during the reporting
period, the following information is reported to the Administrator in
addition to that required under paragraph (k) of this section:
(1) The number of hourly averages available for outlet emission
rates and inlet emission rates.
(2) The standard deviation of hourly averages for outlet emission
rates and
[[Page 132]]
inlet emission rates, as determined in Method 19, section 7.
(3) The lower confidence limit for the mean outlet emission rate and
the upper confidence limit for the mean inlet emission rate, as
calculated in Method 19, section 7.
(4) The ratio of the lower confidence limit for the mean outlet
emission rate and the allowable emission rate, as determined in Method
19, section 7.
(n) If a percent removal efficiency by fuel pretreatment (i.e., %
Rf) is used to determine the overall percent reduction (i.e.,
% Ro) under Sec. 60.45b, the owner or operator of the
affected facility shall submit a signed statement with the report.
(1) Indicating what removal efficiency by fuel pretreatment (i.e., %
Rf) was credited during the reporting period;
(2) Listing the quantity, heat content, and date each pre-treated
fuel shipment was received during the reporting period, the name and
location of the fuel pretreatment facility; and the total quantity and
total heat content of all fuels received at the affected facility during
the reporting period.
(3) Documenting the transport of the fuel from the fuel pretreatment
facility to the steam generating unit.
(4) Including a signed statement from the owner or operator of the
fuel pretreatment facility certifying that the percent removal
efficiency achieved by fuel pretreatment was determined in accordance
with the provisions of Method 19 (appendix A) and listing the heat
content and sulfur content of each fuel before and after fuel
pretreatment.
(o) All records required under this section shall be maintained by
the owner or operator of the affected facility for a period of 2 years
following the date of such record.
(p) The owner or operator of an affected facility described in
Sec. 60.44b(j) or (k) shall maintain records of the following
information for each steam generating unit operating day:
(1) Calendar date,
(2) The number of hours of operation, and
(3) A record of the hourly steam load.
(q) The owner or operator of an affected facility described in
Sec. 60.44b(j) or Sec. 60.44b(k) shall submit to the Administrator a
report containing:
(1) The annual capacity factor over the previous 12 months;
(2) The average fuel nitrogen content during the reporting period,
if residual oil was fired; and
(3) If the affected facility meets the criteria described in
Sec. 60.44b(j), the results of any nitrogen oxides emission tests
required during the reporting period, the hours of operation during the
reporting period, and the hours of operation since the last nitrogen
oxides emission test.
(r) The owner or operator of an affected facility who elects to
demonstrate that the affected facility combusts only very low sulfur oil
under Sec. 60.42b(j)(2) shall obtain and maintain at the affected
facility fuel receipts from the fuel supplier which certify that the oil
meets the definition of distillate oil as defined in Sec. 60.41b. For
the purposes of this section, the oil need not meet the fuel nitrogen
content specification in the definition of distillate oil. Reports shall
be submitted to the Administrator certifying that only very low sulfur
oil meeting this definition was combusted in the affected facility
during the reporting period.
(s) Facility specific nitrogen oxides standard for Cytec Industries
Fortier Plant's C.AOG incinerator located in Westwego, Louisiana:
(1) Definitions.
Oxidation zone is defined as the portion of the C.AOG incinerator
that extends from the inlet of the oxidizing zone combustion air to the
outlet gas stack.
Reducing zone is defined as the portion of the C.AOG incinerator
that extends from the burner section to the inlet of the oxidizing zone
combustion air.
Total inlet air is defined as the total amount of air introduced
into the C.AOG incinerator for combustion of natural gas and chemical
by-product waste and is equal to the sum of the air flow into the
reducing zone and the air flow into the oxidation zone.
(2) Standard for nitrogen oxides. (i) When fossil fuel alone is
combusted, the nitrogen oxides emission limit for fossil fuel in
Sec. 60.44b(a) applies.
[[Page 133]]
(ii) When natural gas and chemical by-product waste are
simultaneously combusted, the nitrogen oxides emission limit is 289 ng/J
(0.67 lb/million Btu) and a maximum of 81 percent of the total inlet air
provided for combustion shall be provided to the reducing zone of the
C.AOG incinerator.
(3) Emission monitoring. (i) The percent of total inlet air provided
to the reducing zone shall be determined at least every 15 minutes by
measuring the air flow of all the air entering the reducing zone and the
air flow of all the air entering the oxidation zone, and compliance with
the percentage of total inlet air that is provided to the reducing zone
shall be determined on a 3-hour average basis.
(ii) The nitrogen oxides emission limit shall be determined by the
compliance and performance test methods and procedures for nitrogen
oxides in Sec. 60.46b(i).
(iii) The monitoring of the nitrogen oxides emission limit shall be
performed in accordance with Sec. 60.48b.
(4) Reporting and recordkeeping requirements. (i) The owner or
operator of the C.AOG incinerator shall submit a report on any
excursions from the limits required by paragraph (a)(2) of this section
to the Administrator with the quarterly report required by paragraph (i)
of this section.
(ii) The owner or operator of the C.AOG incinerator shall keep
records of the monitoring required by paragraph (a)(3) of this section
for a period of 2 years following the date of such record.
(iii) The owner of operator of the C.AOG incinerator shall perform
all the applicable reporting and recordkeeping requirements of this
section.
(t) Facility-specific nitrogen oxides standard for Rohm and Haas
Kentucky Incorporated's Boiler No. 100 located in Louisville, Kentucky:
(1) Definitions.
Air ratio control damper is defined as the part of the low nitrogen
oxides burner that is adjusted to control the split of total combustion
air delivered to the reducing and oxidation portions of the combustion
flame.
Flue gas recirculation line is defined as the part of Boiler No. 100
that recirculates a portion of the boiler flue gas back into the
combustion air.
(2) Standard for nitrogen oxides. (i) When fossil fuel alone is
combusted, the nitrogen oxides emission limit for fossil fuel in
Sec. 60.44b(a) applies.
(ii) When fossil fuel and chemical by-product waste are
simultaneously combusted, the nitrogen oxides emission limit is 473 ng/J
(1.1 lb/million Btu), and the air ratio control damper tee handle shall
be at a minimum of 5 inches (12.7 centimeters) out of the boiler, and
the flue gas recirculation line shall be operated at a minimum of 10
percent open as indicated by its valve opening position indicator.
(3) Emission monitoring for nitrogen oxides. (i) The air ratio
control damper tee handle setting and the flue gas recirculation line
valve opening position indicator setting shall be recorded during each
8-hour operating shift.
(ii) The nitrogen oxides emission limit shall be determined by the
compliance and performance test methods and procedures for nitrogen
oxides in Sec. 60.46b.
(iii) The monitoring of the nitrogen oxides emission limit shall be
performed in accordance with Sec. 60.48b.
(4) Reporting and recordkeeping requirements. (i) The owner or
operator of Boiler No. 100 shall submit a report on any excursions from
the limits required by paragraph (b)(2) of this section to the
Administrator with the quarterly report required by Sec. 60.49b(i).
(ii) The owner or operator of Boiler No. 100 shall keep records of
the monitoring required by paragraph (b)(3) of this section for a period
of 2 years following the date of such record.
(iii) The owner of operator of Boiler No. 100 shall perform all the
applicable reporting and recordkeeping requirements of Sec. 60.49b.
(u) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant
in Elkton, Virginia. (1) This paragraph applies only to the
pharmaceutical manufacturing facility, commonly referred to as the
Stonewall Plant, located at Route 340 South, in Elkton, Virginia
(``site'') and only to the natural gas-fired boilers installed as part
of the powerhouse conversion required pursuant to 40 CFR 52.2454(g). The
requirements of this
[[Page 134]]
paragraph shall apply, and the requirements of Secs. 60.40b through
60.49b(t) shall not apply, to the natural gas-fired boilers installed
pursuant to 40 CFR 52.2454(g).
(i) The site shall equip the natural gas-fired boilers with low
nitrogen oxide (NOX) technology.
(ii) The site shall install, calibrate, maintain, and operate a
continuous monitoring and recording system for measuring NOX
emissions discharged to the atmosphere and opacity using a continuous
emissions monitoring system or a predictive emissions monitoring system.
(iii) Within 180 days of the completion of the powerhouse
conversion, as required by 40 CFR 52.2454, the site shall perform a
stack test to quantify criteria pollutant emissions.
(2) [Reserved]
(v) The owner or operator of an affected facility may submit
electronic quarterly reports for SO2 and/or NOX
and/or opacity in lieu of submitting the written reports required under
paragraphs (h), (i), (j), (k) or (l) of this section. The format of each
quarterly electronic report shall be coordinated with the permitting
authority. The electronic report(s) shall be submitted no later than 30
days after the end of the calendar quarter and shall be accompanied by a
certification statement from the owner or operator, indicating whether
compliance with the applicable emission standards and minimum data
requirements of this subpart was achieved during the reporting period.
Before submitting reports in the electronic format, the owner or
operator shall coordinate with the permitting authority to obtain their
agreement to submit reports in this alternative format.
(w) The reporting period for the reports required under this subpart
is each 6 month period. All reports shall be submitted to the
Administrator and shall be postmarked by the 30th day following the end
of the reporting period.
[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18,
1989; 60 FR 28062, May 30, 1995; 61 FR 14031, Mar. 29, 1996; 62 FR
52641, Oct. 8, 1997; 63 FR 49455, Sept. 16, 1998; 64 FR 7464, Feb. 12,
1999; 65 FR 13243, Mar. 13, 2000]
Subpart Dc--Standards of Performance for Small Industrial-Commercial-
Institutional Steam Generating Units
Source: 55 FR 37683, Sept. 12, 1990, unless otherwise noted.
Sec. 60.40c Applicability and delegation of authority.
(a) Except as provided in paragraph (d) of this section, the
affected facility to which this subpart applies is each steam generating
unit for which construction, modification, or reconstruction is
commenced after June 9, 1989 and that has a maximum design heat input
capacity of 29 megawatts (MW) (100 million Btu per hour (Btu/hr)) or
less, but greater than or equal to 2.9 MW (10 million Btu/hr).
(b) In delegating implementation and enforcement authority to a
State under section 111(c) of the Clean Air Act, Sec. 60.48c(a)(4) shall
be retained by the Administrator and not transferred to a State.
(c) Steam generating units which meet the applicability requirements
in paragraph (a) of this section are not subject to the sulfur dioxide
(SO2) or particulate matter (PM) emission limits, performance
testing requirements, or monitoring requirements under this subpart
(Secs. 60.42c, 60.43c, 60.44c, 60.45c, 60.46c, or 60.47c) during periods
of combustion research, as defined in Sec. 60.41c.
(d) Any temporary change to an existing steam generating unit for
the purpose of conducting combustion research is not considered a
modification under Sec. 60.14.
[55 FR 37683, Sept. 12, 1990, as amended at 61 FR 20736, May 8, 1996]
Sec. 60.41c Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Clean Air Act and in subpart A of this part.
Annual capacity factor means the ratio between the actual heat input
to a steam generating unit from an individual fuel or combination of
fuels during a period of 12 consecutive calendar months and the
potential heat input to the steam generating unit from all fuels had the
steam ch a separate
[[Page 135]]
source (such as a stationary gas turbine, internal combustion engine, or
kiln) provides exhaust gas to a steam generating unit.
Coal means all solid fuels classified as anthracite, bituminous,
subbituminous, or lignite by the American Society for Testing and
Materials in ASTM D388-77, ``Standard Specification for Classification
of Coals by Rank'' (incorporated by reference--see Sec. 60.17); coal
refuse; and petroleum coke. Synthetic fuels derived from coal for the
purpose of creating useful heat, including but not limited to solvent-
refined coal, gasified coal, coal-oil mixtures, and coal-water mixtures,
are included in this definition for the purposes of this subpart.
Coal refuse means any by-product of coal mining or coal cleaning
operations with an ash content greater than 50 percent (by weight) and a
heating value less than 13,900 kilojoules per kilogram (kJ/kg) (6,000
Btu per pound (Btu/lb) on a dry basis.
Cogeneration steam generating unit means a steam generating unit
that simultaneously produces both electrical (or mechanical) and thermal
energy from the same primary energy source.
Combined cycle system means a system in which a separate source
(such as a stationary gas turbine, internal combustion engine, or kiln)
provides exhaust gas to a steam generating unit.
Combustion research means the experimental firing of any fuel or
combination of fuels in a steam generating unit for the purpose of
conducting research and development of more efficient combustion or more
effective prevention or control of air pollutant emissions from
combustion, provided that, during these periods of research and
development, the heat generated is not used for any purpose other than
preheating combustion air for use by that steam generating unit (i.e.,
the heat generated is released to the atmosphere without being used for
space heating, process heating, driving pumps, preheating combustion air
for other units, generating electricity, or any other purpose).
Conventional technology means wet flue gas desulfurization
technology, dry flue gas desulfurization technology, atmospheric
fluidized bed combustion technology, and oil hydrodesulfurization
technology.
Distillate oil means fuel oil that complies with the specifications
for fuel oil numbers 1 or 2, as defined by the American Society for
Testing and Materials in ASTM D396-78, 89, 90, 92, 96, or 98, ``Standard
Specification for Fuel Oils'' (incorporated by reference--see
Sec. 60.17).
Dry flue gas desulfurization technology means a sulfur dioxide
(SO2) control system that is located between the steam
generating unit and the exhaust vent or stack, and that removes sulfur
oxides from the combustion gases of the steam generating unit by
contacting the combustion gases with an alkaline slurry or solution and
forming a dry powder material. This definition includes devices where
the dry powder material is subsequently converted to another form.
Alkaline reagents used in dry flue gas desulfurization systems include,
but are not limited to, lime and sodium compounds.
Duct burner means a device that combusts fuel and that is placed in
the exhaust duct from another source (such as a stationary gas turbine,
internal combustion engine, kiln, etc.) to allow the firing of
additional fuel to heat the exhaust gases before the exhaust gases enter
a steam generating unit.
Emerging technology means any SO2 control system that is
not defined as a conventional technology under this section, and for
which the owner or operator of the affected facility has received
approval from the Administrator to operate as an emerging technology
under Sec. 60.48c(a)(4).
Federally enforceable means all limitations and conditions that are
enforceable by the Administrator, including the requirements of 40 CFR
Parts 60 and 61, requirements within any applicable State implementation
plan, and any permit requirements established under 40 CFR 52.21 or
under 40 CFR 51.18 and 40 CFR 51.24.
Fluidized bed combustion technology means a device wherein fuel is
distributed onto a bed (or series of beds) of limestone aggregate (or
other sorbent materials) for combustion; and these materials are forced
upward in the device by the flow of combustion air and the gaseous
products of combustion. Fluidized bed combustion technology
[[Page 136]]
includes, but is not limited to, bubbling bed units and circulating bed
units.
Fuel pretreatment means a process that removes a portion of the
sulfur in a fuel before combustion of the fuel in a steam generating
unit.
Heat input means heat derived from combustion of fuel in a steam
generating unit and does not include the heat derived from preheated
combustion air, recirculated flue gases, or exhaust gases from other
sources (such as stationary gas turbines, internal combustion engines,
and kilns).
Heat transfer medium means any material that is used to transfer
heat from one point to another point.
Maximum design heat input capacity means the ability of a steam
generating unit to combust a stated maximum amount of fuel (or
combination of fuels) on a steady state basis as determined by the
physical design and characteristics of the steam generating unit.
Natural gas means (1) a naturally occurring mixture of hydrocarbon
and nonhydrocarbon gases found in geologic formations beneath the
earth's surface, of which the principal constituent is methane, or (2)
liquefied petroleum (LP) gas, as defined by the American Society for
Testing and Materials in ASTM D1835-86, 87, 91, or 97, ``Standard
Specification for Liquefied Petroleum Gases'' (incorporated by
reference--see Sec. 60.17).
Noncontinental area means the State of Hawaii, the Virgin Islands,
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern
Mariana Islands.
Oil means crude oil or petroleum, or a liquid fuel derived from
crude oil or petroleum, including distillate oil and residual oil.
Potential sulfur dioxide emission rate means the theoretical
SO2 emissions (nanograms per joule [ng/J], or pounds per
million Btu [lb/million Btu] heat input) that would result from
combusting fuel in an uncleaned state and without using emission control
systems.
Process heater means a device that is primarily used to heat a
material to initiate or promote a chemical reaction in which the
material participates as a reactant or catalyst.
Residual oil means crude oil, fuel oil that does not comply with the
specifications under the definition of distillate oil, and all fuel oil
numbers 4, 5, and 6, as defined by the American Society for Testing and
Materials in ASTM D396-78, 89, 90, 92, 96, or 98, ``Standard
Specification for Fuel Oils'' (incorporated by reference--see
Sec. 60.17).
Steam generating unit means a device that combusts any fuel and
produces steam or heats water or any other heat transfer medium. This
term includes any duct burner that combusts fuel and is part of a
combined cycle system. This term does not include process heaters as
defined in this subpart.
Steam generating unit operating day means a 24-hour period between
12:00 midnight and the following midnight during which any fuel is
combusted at any time in the steam generating unit. It is not necessary
for fuel to be combusted continuously for the entire 24-hour period.
Wet flue gas desulfurization technology means an SO2
control system that is located between the steam generating unit and the
exhaust vent or stack, and that removes sulfur oxides from the
combustion gases of the steam generating unit by contacting the
combustion gases with an alkaline slurry or solution and forming a
liquid material. This definition includes devices where the liquid
material is subsequently converted to another form. Alkaline reagents
used in wet flue gas desulfurization systems include, but are not
limited to, lime, limestone, and sodium compounds.
Wet scrubber system means any emission control device that mixes an
aqueous stream or slurry with the exhaust gases from a steam generating
unit to control emissions of particulate matter (PM) or SO2.
Wood means wood, wood residue, bark, or any derivative fuel or
residue thereof, in any form, including but not limited to sawdust,
sanderdust, wood chips, scraps, slabs, millings, shavings, and processed
pellets made from wood or other forest residues.
[55 FR 37683, Sept. 12, 1990, as amended at 61 FR 20736, May 8, 1996; 65
FR 61752, Oct. 17, 2000]
[[Page 137]]
Sec. 60.42c Standard for sulfur dioxide.
(a) Except as provided in paragraphs (b), (c), and (e) of this
section, on and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, the owner or operator of an affected
facility that combusts only coal shall neither: (1) cause to be
discharged into the atmosphere from that affected facility any gases
that contain SO2 in excess of 10 percent (0.10) of the
potential SO2 emission rate (90 percent reduction); nor (2)
cause to be discharged into the atmosphere from that affected facility
any gases that contain SO2 in excess of 520 ng/J (1.2 lb/
million Btu) heat input. If coal is combusted with other fuels, the
affected facility is subject to the 90 percent SO2 reduction
requirement specified in this paragraph and the emission limit is
determined pursuant to paragraph (e)(2) of this section.
(b) Except as provided in paragraphs (c) and (e) of this section, on
and after the date on which the initial performance test is completed or
required to be completed under Sec. 60.8 of this part, whichever date
comes first, the owner or operator of an affected facility that:
(1) Combusts coal refuse alone in a fluidized bed combustion steam
generating unit shall neither:
(i) Cause to be discharged into the atmosphere from that affected
facility any gases that contain SO2 in excess of 20 percent
(0.20) of the potential SO2 emission rate (80 percent
reduction); nor
(ii) Cause to be discharged into the atmosphere from that affected
facility any gases that contain SO2 in excess of 520 ng/J
(1.2 lb/million Btu) heat input. If coal is fired with coal refuse, the
affected facility is subject to paragraph (a) of this section. If oil or
any other fuel (except coal) is fired with coal refuse, the affected
facility is subject to the 90 percent SO2 reduction
requirement specified in paragraph (a) of this section and the emission
limit determined pursuant to paragraph (e)(2) of this section.
(2) Combusts only coal and that uses an emerging technology for the
control of SO2 emissions shall neither:
(i) Cause to be discharged into the atmosphere from that affected
facility any gases that contain SO2 in excess of 50 percent
(0.50) of the potential SO2 emission rate (50 percent
reduction); nor
(ii) Cause to be discharged into the atmosphere from that affected
facility any gases that contain SO2 in excess of 260 ng/J
(0.60 lb/million Btu) heat input. If coal is combusted with other fuels,
the affected facility is subject to the 50 percent SO2
reduction requirement specified in this paragraph and the emission limit
determined pursuant to paragraph (e)(2) of this section.
(c) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts coal, alone or in combination with any other fuel, and is
listed in paragraphs (c)(1), (2), (3), or (4) of this section shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain SO2 in excess of the emission limit
determined pursuant to paragraph (e)(2) of this section. Percent
reduction requirements are not applicable to affected facilities under
paragraphs (c)(1), (2), (3), or (4).
(1) Affected facilities that have a heat input capacity of 22 MW (75
million Btu/hr) or less.
(2) Affected facilities that have an annual capacity for coal of 55
percent (0.55) or less and are subject to a Federally enforceable
requirement limiting operation of the affected facility to an annual
capacity factor for coal of 55 percent (0.55) or less.
(3) Affected facilities located in a noncontinental area.
(4) Affected facilities that combust coal in a duct burner as part
of a combined cycle system where 30 percent (0.30) or less of the heat
entering the steam generating unit is from combustion of coal in the
duct burner and 70 percent (0.70) or more of the heat entering the steam
generating unit is from exhaust gases entering the duct burner.
(d) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts oil shall cause to be discharged into the
[[Page 138]]
atmosphere from that affected facility any gases that contain
SO2 in excess of 215 ng/J (0.50 lb/million Btu) heat input;
or, as an alternative, no owner or operator of an affected facility that
combusts oil shall combust oil in the affected facility that contains
greater than 0.5 weight percent sulfur. The percent reduction
requirements are not applicable to affected facilities under this
paragraph.
(e) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts coal, oil, or coal and oil with any other fuel shall cause
to be discharged into the atmosphere from that affected facility any
gases that contain SO2 in excess of the following:
(1) The percent of potential SO2 emission rate required
under paragraph (a) or (b)(2) of this section, as applicable, for any
affected facility that
(i) Combusts coal in combination with any other fuel,
(ii) Has a heat input capacity greater than 22 MW (75 million Btu/
hr), and
(iii) Has an annual capacity factor for coal greater than 55 percent
(0.55); and
(2) The emission limit determined according to the following formula
for any affected facility that combusts coal, oil, or coal and oil with
any other fuel:
Es=(Ka Ha+Kb
Hb+Kc Hc)/
Ha+Hb+Hc)
where:
Es is the SO2 emission limit, expressed in
ng/J or lb/million Btu heat input,
Ka is 520 ng/J (1.2 lb/million Btu),
Kb is 260 ng/J (0.60 lb/million Btu),
Kc is 215 ng/J (0.50 lb/million Btu),
Ha is the heat input from the combustion of coal, except
coal combusted in an affected facility subject to paragraph (b)(2) of
this section, in Joules (J) [million Btu]
Hb is the heat input from the combustion of coal in an
affected facility subject to paragraph (b)(2) of this section, in J
(million Btu)
Hc is the heat input from the combustion of oil, in J
(million Btu).
(f) Reduction in the potential SO2 emission rate through
fuel pretreatment is not credited toward the percent reduction
requirement under paragraph (b)(2) of this section unless:
(1) Fuel pretreatment results in a 50 percent (0.50) or greater
reduction in the potential SO2 emission rate; and
(2) Emissions from the pretreated fuel (without either combustion or
post-combustion SO2 control) are equal to or less than the
emission limits specified under paragraph (b)(2) of this section.
(g) Except as provided in paragraph (h) of this section, compliance
with the percent reduction requirements, fuel oil sulfur limits, and
emission limits of this section shall be determined on a 30-day rolling
average basis.
(h) For affected facilities listed under paragraphs (h)(1), (2), or
(3) of this section, compliance with the emission limits or fuel oil
sulfur limits under this section may be determined based on a
certification from the fuel supplier, as described under
Sec. 60.48c(f)(1), (2), or (3), as applicable.
(1) Distillate oil-fired affected facilities with heat input
capacities between 2.9 and 29 MW (10 and 100 million Btu/hr).
(2) Residual oil-fired affected facilities with heat input
capacities between 2.9 and 8.7 MW (10 and 30 million Btu/hr).
(3) Coal-fired facilities with heat input capacities between 2.9 and
8.7 MW (10 and 30 million Btu/hr).
(i) The SO2 emission limits, fuel oil sulfur limits, and
percent reduction requirements under this section apply at all times,
including periods of startup, shutdown, and malfunction.
(j) Only the heat input supplied to the affected facility from the
combustion of coal and oil is counted under this section. No credit is
provided for the heat input to the affected facility from wood or other
fuels or for heat derived from exhaust gases from other sources, such as
stationary gas turbines, internal combustion engines, and kilns.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.43c Standard for particulate matter.
(a) On and after the date on which the initial performance test is
completed or required to be completed
[[Page 139]]
under Sec. 60.8 of this part, whichever date comes first, no owner or
operator of an affected facility that combusts coal or combusts mixtures
of coal with other fuels and has a heat input capacity of 8.7 MW (30
million Btu/hr) or greater, shall cause to be discharged into the
atmosphere from that affected facility any gases that contain PM in
excess of the following emission limits:
(1) 22 ng/J (0.051 lb/million Btu) heat input if the affected
facility combusts only coal, or combusts coal with other fuels and has
an annual capacity factor for the other fuels of 10 percent (0.10) or
less.
(2) 43 ng/J (0.10 lb/million Btu) heat imput if the affected
facility combusts coal with other fuels, has an annual capacity factor
for the other fuels greater than 10 percent (0.10), and is subject to a
federally enforceable requirement limiting operation of the affected
facility to an annual capacity factor greater than 10 percent (0.10) for
fuels other than coal.
(b) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts wood or combusts mixtures of wood with other fuels (except
coal) and has a heat input capacity of 8.7 MW (30 million Btu/hr) or
greater, shall cause to be discharged into the atmosphere from that
affected facility any gases that contain PM in excess of the following
emissions limits:
(1) 43 ng/J (0.10 lb/million Btu) heat input if the affected
facility has an annual capacity factor for wood greater than 30 percent
(0.30); or
(2) 130 ng/J (0.30 lb/million Btu) heat input if the affected
facility has an annual capacity factor for wood of 30 percent (0.30) or
less and is subject to a federally enforceable requirement limiting
operation of the affected facility to an annual capacity factor for wood
of 30 percent (0.30) or less.
(c) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator of an affected facility
that combusts coal, wood, or oil and has a heat input capacity of 8.7 MW
(30 million Btu/hr) or greater shall cause to be discharged into the
atmosphere from that affected facility any gases that exhibit greater
than 20 percent opacity (6-minute average), except for one 6-minute
period per hour of not more than 27 percent opacity.
(d) The PM and opacity standards under this section apply at all
times, except during periods of startup, shutdown, or malfunction.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.44c Compliance and performance test methods and procedures for sulfur dioxide.
(a) Except as provided in paragraphs (g) and (h) of this section and
in Sec. 60.8(b), performance tests required under Sec. 60.8 shall be
conducted following the procedures specified in paragraphs (b), (c),
(d), (e), and (f) of this section, as applicable. Section 60.8(f) does
not apply to this section. The 30-day notice required in Sec. 60.8(d)
applies only to the initial performance test unless otherwise specified
by the Administrator.
(b) The initial performance test required under Sec. 60.8 shall be
conducted over 30 consecutive operating days of the steam generating
unit. Compliance with the percent reduction requirements and
SO2 emission limits under Sec. 60.42c shall be determined
using a 30-day average. The first operating day included in the initial
performance test shall be scheduled within 30 days after achieving the
maximum production rate at which the affect facility will be operated,
but not later than 180 days after the initial startup of the facility.
The steam generating unit load during the 30-day period does not have to
be the maximum design heat input capacity, but must be representative of
future operating conditions.
(c) After the initial performance test required under paragraph (b)
and Sec. 60.8, compliance with the percent reduction requirements and
SO2 emission limits under Sec. 60.42c is based on the average
percent reduction and the average S02 emission rates for 30
consecutive steam generating unit operating days. A separate performance
test is completed at the end of each steam generating unit
[[Page 140]]
operating day, and a new 30-day average percent reduction and
SO2 emission rate are calculated to show compliance with the
standard.
(d) If only coal, only oil, or a mixture of coal and oil is
combusted in an affected facility, the procedures in Method 19 are used
to determine the hourly SO2 emission rate (Eho)
and the 30-day average SO2 emission rate (Eao).
The hourly averages used to compute the 30-day averages are obtained
from the continuous emission monitoring system (CEMS). Method 19 shall
be used to calculate Eao when using daily fuel sampling or
Method 6B.
(e) If coal, oil, or coal and oil are combusted with other fuels:
(1) An adjusted Eho (Ehoo) is used in Equation
19-19 of Method 19 to compute the adjusted Eao
(Eaoo). The Ehoo is computed using the following
formula:
Ehoo=[Eho-Ew(1-Xk)]/
Xk
where:
Ehoo is the adjusted Eho, ng/J (lb/million
Btu)
Eho is the hourly SO2 emission rate, ng/J
(lb/million Btu)
Ew is the SO2 concentration in fuels other
than coal and oil combusted in the affected facility, as determined by
fuel sampling and analysis procedures in Method 9, ng/J (lb/million
Btu). The value Ew for each fuel lot is used for each hourly
average during the time that the lot is being combusted. The owner or
operator does not have to measure Ew if the owner or operator
elects to assume Ew=0.
Xk is the fraction of the total heat input from fuel
combustion derived from coal and oil, as determined by applicable
procedures in Method 19.
(2) The owner or operator of an affected facility that qualifies
under the provisions of Sec. 60.42c(c) or (d) [where percent reduction
is not required] does not have to measure the parameters Ew
or Xk if the owner or operator of the affected facility
elects to measure emission rates of the coal or oil using the fuel
sampling and analysis procedures under Method 19.
(f) Affected facilities subject to the percent reduction
requirements under Sec. 60.42c(a) or (b) shall determine compliance with
the SO2 emission limits under Sec. 60.42c pursuant to
paragraphs (d) or (e) of this section, and shall determine compliance
with the percent reduction requirements using the following procedures:
(1) If only coal is combusted, the percent of potential
SO2 emission rate is computed using the following formula:
%Ps=100(1-%Rg/100)(1-%Rf/100)
where
%Ps is the percent of potential SO2 emission
rate, in percent
%Rg is the SO2 removal efficiency of the
control device as determined by Method 19, in percent
%Rf is the SO2 removal efficiency of fuel
pretreatment as determined by Method 19, in percent
(2) If coal, oil, or coal and oil are combusted with other fuels,
the same procedures required in paragraph (f)(1) of this section are
used, except as provided for in the following:
(i) To compute the %Ps, an adjusted %Rg
(%Rgo) is computed from Eaoo from paragraph (e)(1)
of this section and an adjusted average SO2 inlet rate
(Eaio) using the following formula:
%Rgo=100 [1.0- Eaoo/Eaio)]
where:
%Rgo is the adjusted %Rg, in percent
Eaoo is the adjusted Eao, ng/J (lb/million
Btu)
Eaio is the adjusted average SO2 inlet rate,
ng/J (lb/million Btu)
(ii) To compute Eaio, an adjusted hourly SO2
inlet rate (Ehio) is used. The Ehio is computed
using the following formula:
Ehio=[Ehi- Ew (1-Xk)]/
Xk
where:
Ehio is the adjusted Ehi, ng/J (lb/million
Btu)
Ehi is the hourly SO2 inlet rate, ng/J (lb/
million Btu)
Ew is the SO2 concentration in fuels other
than coal and oil combusted in the affected facility, as determined by
fuel sampling and analysis procedures in Method 19, ng/J (lb/million
Btu). The value Ew for each fuel lot is used for each hourly
average during the time that the lot is being combusted. The owner or
operator does not have to measure Ew if the owner or operator
elects to assume Ew = O.
Xk is the fraction of the total heat input from fuel
combustion derived from coal and oil, as determined by applicable
procedures in Method 19.
(g) For oil-fired affected facilities where the owner or operator
seeks to demonstrate compliance with the fuel oil sulfur limits under
Sec. 60.42c based on shipment fuel sampling, the initial performance
test shall consist of sampling
[[Page 141]]
and analyzing the oil in the initial tank of oil to be fired in the
steam generating unit to demonstrate that the oil contains 0.5 weight
percent sulfur or less. Thereafter, the owner or operator of the
affected facility shall sample the oil in the fuel tank after each new
shipment of oil is received, as described under Sec. 60.46c(d)(2).
(h) For affected facilities subject to Sec. 60.42c(h)(1), (2), or
(3) where the owner or operator seeks to demonstrate compliance with the
SO2 standards based on fuel supplier certification, the
performance test shall consist of the certification, the certification
from the fuel supplier, as described under Sec. 60.48c(f)(1), (2), or
(3), as applicable.
(i) The owner or operator of an affected facility seeking to
demonstrate compliance with the SO2 standards under
Sec. 60.42c(c)(2) shall demonstrate the maximum design heat input
capacity of the steam generating unit by operating the steam generating
unit at this capacity for 24 hours. This demonstration shall be made
during the initial performance test, and a subsequent demonstration may
be requested at any other time. If the demonstrated 24-hour average
firing rate for the affected facility is less than the maximum design
heat input capacity stated by the manufacturer of the affected facility,
the demonstrated 24-hour average firing rate shall be used to determine
the annual capacity factor for the affected facility; otherwise, the
maximum design heat input capacity provided by the manufacturer shall be
used.
(j) The owner or operator of an affected facility shall use all
valid SO2 emissions data in calculating %Ps and
Eho under paragraphs (d), (e), or (f) of this section, as
applicable, whether or not the minimum emissions data requirements under
Sec. 60.46c(f) are achieved. All valid emissions data, including valid
data collected during periods of startup, shutdown, and malfunction,
shall be used in calculating %Ps or Eho pursuant
to paragraphs (d), (e), or (f) of this section, as applicable.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.45c Compliance and performance test methods and procedures for particulate matter.
(a) The owner or operator of an affected facility subject to the PM
and/or opacity standards under Sec. 60.43c shall conduct an initial
performance test as required under Sec. 60.8, and shall conduct
subsequent performance tests as requested by the Administrator, to
determine compliance with the standards using the following procedures
and reference methods.
(1) Method 1 shall be used to select the sampling site and the
number of traverse sampling points.
(2) Method 3 shall be used for gas analysis when applying Method 5,
Method 5B, or Method 17.
(3) Method 5, Method 5B, or Method 17 shall be used to measure the
concentration of PM as follows:
(i) Method 5 may be used only at affected facilities without wet
scrubber systems.
(ii) Method 17 may be used at affected facilities with or without
wet scrubber systems provided the stack gas temperature does not exceed
a temperature of 160 deg.C (320 deg.F). The procedures of Sections 8.1
and 11.1 of Method 5B may be used in Method 17 only if Method 17 is used
in conjunction with a wet scrubber system. Method 17 shall not be used
in conjunction with a wet scrubber system if the effluent is saturated
or laden with water droplets.
(iii) Method 5B may be used in conjunction with a wet scrubber
system.
(4) The sampling time for each run shall be at least 120 minutes and
the minimum sampling volume shall be 1.7 dry standard cubic meters
(dscm) [60 dry standard cubic feet (dscf)] except that smaller sampling
times or volumes may be approved by the Administrator when necessitated
by process variables or other factors.
(5) For Method 5 or Method 5B, the temperature of the sample gas in
the probe and filter holder shall be monitored and maintained at
16014 deg.C (32025 deg.F).
(6) For determination of PM emissions, an oxygen or carbon dioxide
measurement shall be obtained simultaneously with each run of Method 5,
Method 5B, or Method 17 by traversing
[[Page 142]]
the duct at the same sampling location.
(7) For each run using Method 5, Method 5B, or Method 17, the
emission rates expressed in ng/J (lb/million Btu) heat input shall be
determined using:
(i) The oxygen or carbon dioxide measurements and PM measurements
obtained under this section,
(ii) The dry basis F-factor, and
(iii) The dry basis emission rate calculation procedure contained in
Method 19 (appendix A).
(8) Method 9 (6-minute average of 24 observations) shall be used for
determining the opacity of stack emissions.
(b) The owner or operator of an affected facility seeking to
demonstrate compliance with the PM standards under Sec. 60.43c(b)(2)
shall demonstrate the maximum design heat input capacity of the steam
generating unit by operating the steam generating unit at this capacity
for 24 hours. This demonstration shall be made during the initial
performance test, and a subsequent demonstration may be requested at any
other time. If the demonstrated 24-hour average firing rate for the
affected facility is less than the maximum design heat input capacity
stated by the manufacturer of the affected facility, the demonstrated
24-hour average firing rate shall be used to determine the annual
capacity factor for the affected facility; otherwise, the maximum design
heat input capacity provided by the manufacturer shall be used.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.46c Emission monitoring for sulfur dioxide
(a) Except as provided in paragraphs (d) and (e) of this section,
the owner or operator of an affected facility subject to the
SO2 emission limits under Sec. 60.42c shall install,
calibrate, maintain, and operate a CEMS for measuring SO2
concentrations and either oxygen or carbon dioxide concentrations at the
outlet of the SO2 control device (or the outlet of the steam
generating unit if no SO2 control device is used), and shall
record the output of the system. The owner or operator of an affected
facility subject to the percent reduction requirements under Sec. 60.42c
shall measure SO2 concentrations and either oxygen or carbon
dioxide concentrations at both the inlet and outlet of the
SO2 control device.
(b) The 1-hour average SO2 emission rates measured by a
CEMS shall be expressed in ng/J or lb/million Btu heat input and shall
be used to calculate the average emission rates under Sec. 60.42c. Each
1-hour average SO2 emission rate must be based on at least 30
minutes of operation and include at least 2 data points representing two
15-minute periods. Hourly SO2 emission rates are not
calculated if the affected facility is operated less than 30 minutes in
a 1-hour period and are not counted toward determination of a steam
generating unit operating day.
(c) The procedures under Sec. 60.13 shall be followed for
installation, evaluation, and operation of the CEMS.
(1) All CEMS shall be operated in accordance with the applicable
procedures under Performance Specifications 1, 2, and 3 (appendix B).
(2) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with Procedure 1 (appendix F).
(3) For affected facilities subject to the percent reduction
requirements under Sec. 60.42c, the span value of the SO2
CEMS at the inlet to the SO2 control device shall be 125
percent of the maximum estimated hourly potential SO2
emission rate of the fuel combusted, and the span value of the
SO2 CEMS at the outlet from the SO2 control device
shall be 50 percent of the maximum estimated hourly potential
SO2 emission rate of the fuel combusted.
(4) For affected facilities that are not subject to the percent
reduction requirements of Sec. 60.42c, the span value of the
SO2 CEMS at the outlet from the SO2 control device
(or outlet of the steam generating unit if no SO2 control
device is used) shall be 125 percent of the maximum estimated hourly
potential SO2 emission rate of the fuel combusted.
(d) As an alternative to operating a CEMS at the inlet to the
SO2 control device (or outlet of the steam generating unit if
no SO2 control device is used) as required under paragraph
(a) of this section, an owner or operator may elect to determine the
average
[[Page 143]]
SO2 emission rate by sampling the fuel prior to combustion.
As an alternative to operating a CEMS at the outlet from the
SO2 control device (or outlet of the steam generating unit if
no SO2 control device is used) as required under paragraph
(a) of this section, an owner or operator may elect to determine the
average SO2 emission rate by using Method 6B. Fuel sampling
shall be conducted pursuant to either paragraph (d)(1) or (d)(2) of this
section. Method 6B shall be conducted pursuant to paragraph (d)(3) of
this section.
(1) For affected facilities combusting coal or oil, coal or oil
samples shall be collected daily in an as-fired condition at the inlet
to the steam generating unit and analyzed for sulfur content and heat
content according the Method 19. Method 19 provides procedures for
converting these measurements into the format to be used in calculating
the average SO2 input rate.
(2) As an alternative fuel sampling procedure for affected
facilities combusting oil, oil samples may be collected from the fuel
tank for each steam generating unit immediately after the fule tank is
filled and before any oil is combusted. The owner or operator of the
affected facility shall analyze the oil sample to determine the sulfur
content of the oil. If a partially empty fuel tank is refilled, a new
sample and analysis of the fuel in the tank would be required upon
filling. Results of the fuel analysis taken after each new shipment of
oil is received shall be used as the daily value when calculating the
30-day rolling average until the next shipment is received. If the fuel
analysis shows that the sulfur content in the fuel tank is greater than
0.5 weight percent sulfur, the owner or operator shall ensure that the
sulfur content of subsequent oil shipments is low enough to cause the
30-day rolling average sulfur content to be 0.5 weight percent sulfur or
less.
(3) Method 6B may be used in lieu of CEMS to measure SO2
at the inlet or outlet of the SO2 control system. An initial
stratification test is required to verify the adequacy of the Method 6B
sampling location. The stratification test shall consist of three paired
runs of a suitable SO2 and carbon dioxide measurement train
operated at the candidate location and a second similar train operated
according to the procedures in Sec. 3.2 and the applicable procedures in
section 7 of Performance Specification 2 (appendix B). Method 6B, Method
6A, or a combination of Methods 6 and 3 or Methods 6C and 3A are
suitable measurement techniques. If Method 6B is used for the second
train, sampling time and timer operation may be adjusted for the
stratification test as long as an adequate sample volume is collected;
however, both sampling trains are to be operated similarly. For the
location to be adequate for Method 6B 24-hour tests, the mean of the
absolute difference between the three paired runs must be less than 10
percent (0.10).
(e) The monitoring requirements of paragraphs (a) and (d) of this
section shall not apply to affected facilities subject to Sec. 60.42c(h)
(1), (2), or (3) where the owner or operator of the affected facility
seeks to demonstrate compliance with the SO2 standards based
on fuel supplier certification, as described under Sec. 60.48c(f) (1),
(2), or (3), as applicable.
(f) The owner or operator of an affected facility operating a CEMS
pursuant to paragraph (a) of this section, or conducting as-fired fuel
sampling pursuant to paragraph (d)(1) of this section, shall obtain
emission data for at least 75 percent of the operating hours in at least
22 out of 30 successive steam generating unit operating days. If this
minimum data requirement is not met with a single monitoring system, the
owner or operator of the affected facility shall supplement the emission
data with data collected with other monitoring systems as approved by
the Administrator.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.47c Emission monitoring for particulate matter.
(a) The owner or operator of an affected facility combusting coal,
residual oil, or wood that is subject to the opacity standards under
Sec. 60.43c shall install, calibrate, maintain, and operate a COMS for
measuring the opacity of the emissions discharged to the atmosphere and
record the output of the system.
[[Page 144]]
(b) All COMS for measuring opacity shall be operated in accordance
with the applicable procedures under Performance Specification 1
(appendix B). The span value of the opacity COMS shall be between 60 and
80 percent.
[55 FR 37683, Sept. 12, 1990, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.48c Reporting and recordkeeping requirements.
(a) The owner or operator of each affected facility shall submit
notification of the date of construction or reconstruction, anticipated
startup, and actual startup, as provided by Sec. 60.7 of this part. This
notification shall include:
(1) The design heat input capacity of the affected facility and
identification of fuels to be combusted in the affected facility.
(2) If applicable, a copy of any Federally enforceable requirement
that limits the annual capacity factor for any fuel or mixture of fuels
under Sec. 60.42c, or Sec. 60.43c.
(3) The annual capacity factor at which the owner or operator
anticipates operating the affected facility based on all fuels fired and
based on each individual fuel fired.
(4) Notification if an emerging technology will be used for
controlling SO2 emissions. The Administrator will examine the
description of the control device and will determine whether the
technology qualifies as an emerging technology. In making this
determination, the Administrator may require the owner or operator of
the affected facility to submit additional information concerning the
control device. The affected facility is subject to the provisions of
Sec. 60.42c(a) or (b)(1), unless and until this determination is made by
the Administrator.
(b) The owner or operator of each affected facility subject to the
SO2 emission limits of Sec. 60.42c, or the PM or opacity
limits of Sec. 60.43c, shall submit to the Administrator the performance
test data from the initial and any subsequent performance tests and, if
applicable, the performance evaluation of the CEMS and/or COMS using the
applicable performance specifications in appendix B.
(c) The owner or operator of each coal-fired, residual oil-fired, or
wood-fired affected facility subject to the opacity limits under
Sec. 60.43c(c) shall submit excess emission reports for any excess
emissions from the affected facility which occur during the reporting
period.
(d) The owner or operator of each affected facility subject to the
SO2 emission limits, fuel oil sulfur limits, or percent
reduction requirements under Sec. 60.42c shall submit reports to the
Administrator.
(e) The owner or operator of each affected facility subject to the
SO2 emission limits, fuel oil sulfur limits, or percent
reduction requirements under Sec. 60.43c shall keep records and submit
reports as required under paragraph (d) of this section, including the
following information, as applicable.
(1) Calendar dates covered in the reporting period.
(2) Each 30-day average SO2 emission rate (nj/J or lb/
million Btu), or 30-day average sulfur content (weight percent),
calculated during the reporting period, ending with the last 30-day
period; reasons for any noncompliance with the emission standards; and a
description of corrective actions taken.
(3) Each 30-day average percent of potential SO2 emission
rate calculated during the reporting period, ending with the last 30-day
period; reasons for any noncompliance with the emission standards; and a
description of the corrective actions taken.
(4) Identification of any steam generating unit operating days for
which SO2 or diluent (oxygen or carbon dioxide) data have not
been obtained by an approved method for at least 75 percent of the
operating hours; justification for not obtaining sufficient data; and a
description of corrective actions taken.
(5) Identification of any times when emissions data have been
excluded from the calculation of average emission rates; justification
for excluding data; and a description of corrective actions taken if
data have been excluded for periods other than those during which coal
or oil were not combusted in the steam generating unit.
(6) Identification of the F factor used in calculations, method of
determination, and type of fuel combusted.
[[Page 145]]
(7) Identification of whether averages have been obtained based on
CEMS rather than manual sampling methods.
(8) If a CEMS is used, identification of any times when the
pollutant concentration exceeded the full span of the CEMS.
(9) If a CEMS is used, description of any modifications to the CEMS
that could affect the ability of the CEMS to comply with Performance
Specifications 2 or 3 (appendix B).
(10) If a CEMS is used, results of daily CEMS drift tests and
quarterly accuracy assessments as required under appendix F, Procedure
1.
(11) If fuel supplier certification is used to demonstrate
compliance, records of fuel supplier certification is used to
demonstrate compliance, records of fuel supplier certification as
described under paragraph (f)(1), (2), or (3) of this section, as
applicable. In addition to records of fuel supplier certifications, the
report shall include a certified statement signed by the owner or
operator of the affected facility that the records of fuel supplier
certifications submitted represent all of the fuel combusted during the
reporting period.
(f) Fuel supplier certification shall include the following
information:
(1) For distillate oil:
(i) The name of the oil supplier; and
(ii) A statement from the oil supplier that the oil complies with
the specifications under the definition of distillate oil in
Sec. 60.41c.
(2) For residual oil:
(i) The name of the oil supplier;
(ii) The location of the oil when the sample was drawn for analysis
to determine the sulfur content of the oil, specifically including
whether the oil was sampled as delivered to the affected facility, or
whether the sample was drawn from oil in storage at the oil supplier's
or oil refiner's facility, or other location;
(iii) The sulfur content of the oil from which the shipment came (or
of the shipment itself); and
(iv) The method used to determine the sulfur content of the oil.
(3) For coal:
(i) The name of the coal supplier;
(ii) The location of the coal when the sample was collected for
analysis to determine the properties of the coal, specifically including
whether the coal was sampled as delivered to the affected facility or
whether the sample was collected from coal in storage at the mine, at a
coal preparation plant, at a coal supplier's facility, or at another
location. The certification shall include the name of the coal mine (and
coal seam), coal storage facility, or coal preparation plant (where the
sample was collected);
(iii) The results of the analysis of the coal from which the
shipment came (or of the shipment itself) including the sulfur content,
moisture content, ash content, and heat content; and
(iv) The methods used to determine the properties of the coal.
(g) The owner or operator of each affected facility shall record and
maintain records of the amounts of each fuel combusted during each day.
(h) The owner or operator of each affected facility subject to a
Federally enforceable requirement limiting the annual capacity factor
for any fuel or mixture of fuels under Sec. 60.42c or Sec. 60.43c shall
calculate the annual capacity factor individually for each fuel
combusted. The annual capacity factor is determined on a 12-month
rolling average basis with a new annual capacity factor calculated at
the end of the calendar month.
(i) All records required under this section shall be maintained by
the owner or operator of the affected facility for a period of two years
following the date of such record.
(j) The reporting period for the reports required under this subpart
is each six-month period. All reports shall be submitted to the
Administrator and shall be postmarked by the 30th day following the end
of the reporting period.
[55 FR 37683, Sept. 12, 1990, as amended at 64 FR 7465, Feb. 12, 1999;
65 FR 61753, Oct. 17, 2000]
Subpart E--Standards of Performance for Incinerators
Sec. 60.50 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to each
incinerator of more than 45 metric tons per day charging
[[Page 146]]
rate (50 tons/day), which is the affected facility.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after August 17, 1971, is subject to the
requirements of this subpart.
[42 FR 37936, July 25, 1977]
Sec. 60.51 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Incinerator means any furnace used in the process of burning
solid waste for the purpose of reducing the volume of the waste by
removing combustible matter.
(b) Solid waste means refuse, more than 50 percent of which is
municipal type waste consisting of a mixture of paper, wood, yard
wastes, food wastes, plastics, leather, rubber, and other combustibles,
and noncombustible materials such as glass and rock.
(c) Day means 24 hours.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20792, June 14, 1974]
Sec. 60.52 Standard for particulate matter.
(a) On and after the date on which the initial performance test is
completed or required to be completed under Sec. 60.8 of this part,
whichever date comes first, no owner or operator subject to the
provisions of this part shall cause to be discharged into the atmosphere
from any affected facility any gases which contain particulate matter in
excess of 0.18 g/dscm (0.08 gr/dscf) corrected to 12 percent
CO2.
[39 FR 20792, June 14, 1974, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.53 Monitoring of operations.
(a) The owner or operator of any incinerator subject to the
provisions of this part shall record the daily charging rates and hours
of operation.
Sec. 60.54 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
(b) The owner or operator shall determine compliance with the
particulate matter standard in Sec. 60.52 as follows:
(1) The concentration (c12) of particulate matter,
corrected to 12 percent CO2, shall be computed for each run
using the following equation:
c12 = cs (12/%CO2)
where:
c12=concentration of particulate matter, corrected to 12
percent CO2, g/dscm (gr/dscf).
cs=concentration of particulate matter, g/dscm (gr/dscf).
%CO2=CO2 concentration, percent dry basis.
(2) Method 5 shall be used to determine the particulate matter
concentration (cs). The sampling time and sample volume for
each run shall be at least 60 minutes and 0.85 dscm (30 dscf).
(3) The emission rate correction factor, integrated or grab sampling
and analysis procedure of Method 3B shall be used to determine
CO2 concentration (%CO2).
(i) The CO2 sample shall be obtained simultaneously with,
and at the same traverse points as, the particulate run. If the
particulate run has more than 12 traverse points, the CO2
traverse points may be reduced to 12 if Method 1 is used to locate the
12 CO2 traverse points. If individual CO2 samples
are taken at each traverse point, the CO2 concentration
(%CO2) used in the correction equation shall be the
arithmetic mean of the sample CO2 concentrations at all
traverse points.
(ii) If sampling is conducted after a wet scrubber, an ``adjusted''
CO2 concentration [(%CO2)adj], which
accounts for the effects of CO2 absorption and dilution air,
may be used instead of the CO2 concentration determined in
this paragraph. The adjusted CO2 concentration shall be
determined by either of the procedures in paragraph (c) of this section.
(c) The owner or operator may use either of the following procedures
to determine the adjusted CO2 concentration.
(1) The volumetric flow rates at the inlet and outlet of the wet
scrubber and the inlet CO2 concentration may be used to
determine the adjusted CO2 concentration
[(%CO2)adj] using the following equation:
[[Page 147]]
(%CO2)adj=(%CO2)di
(Qdi/Qdo)
where:
(%CO2)adj=adjusted outlet CO2
concentration, percent dry basis.
(%CO2)di=CO2 concentration measured
before the scrubber, percent dry basis.
Qdi=volumetric flow rate of effluent gas before the wet
scrubber, dscm/min (dscf/min).
Qdo=volumetric flow rate of effluent gas after the wet
scrubber, dscm/min (dscf/min).
(i) At the outlet, Method 5 is used to determine the volumetric flow
rate (Qdo) of the effluent gas.
(ii) At the inlet, Method 2 is used to determine the volumetric flow
rate (Qdi) of the effluent gas as follows: Two full velocity
traverses are conducted, one immediately before and one immediately
after each particulate run conducted at the outlet, and the results are
averaged.
(iii) At the inlet, the emission rate correction factor, integrated
sampling and analysis procedure of Method 3B is used to determine the
CO2 concentration [(%CO2)di] as
follows: At least nine sampling points are selected randomly from the
velocity traverse points and are divided randomly into three sets, equal
in number of points; the first set of three or more points is used for
the first run, the second set for the second run, and the third set for
the third run. The CO2 sample is taken simultaneously with
each particulate run being conducted at the outlet, by traversing the
three sampling points (or more) and sampling at each point for equal
increments of time.
(2) Excess air measurements may be used to determine the adjusted
CO2 concentration [(%CO2)adj] using the
following equation:
(%CO2)adj=(%CO2)di
[(100+%EAi)/(100+%EAo)]
where:
(%CO2)adj=adjusted outlet CO2
concentration, percent dry basis.
(%CO2)di=CO2 concentration at the inlet
of the wet scrubber, percent dry basis.
%EAi=excess air at the inlet of the scrubber, percent.
%EAo=excess air at the outlet of the scrubber, percent.
(i) A gas sample is collected as in paragraph (c)(1)(iii) of this
section and the gas samples at both the inlet and outlet locations are
analyzed for CO2, O2, and N2.
(ii) Equation 3B-3 of Method 3B is used to compute the percentages
of excess air at the inlet and outlet of the wet scrubber.
[54 FR 6665, Feb. 14, 1989, as amended at 55 FR 5212, Feb. 14, 1990; 65
FR 61753, Oct. 17, 2000]
Subpart Ea--Standards of Performance for Municipal Waste Combustors for
Which Construction is Commenced After December 20, 1989 and on or Before
September 20, 1994
Source: 56 FR 5507, Feb. 11, 1991, unless otherwise noted.
Sec. 60.50a Applicability and delegation of authority.
(a) The affected facility to which this subpart applies is each
municipal waste combustor unit with a municipal waste combustor unit
capacity greater than 225 megagrams per day (250 tons per day) of
municipal solid waste for which construction, modification, or
reconstruction is commenced as specified in paragraphs (a)(1) and (a)(2)
of this section.
(1) Construction is commenced after December 20, 1989 and on or
before September 20, 1994.
(2) Modification or reconstruction is commenced after December 20,
1989 and on or before June 19, 1996.
(b) [Reserved]
(c) Any unit combusting a single-item waste stream of tires is not
subject to this subpart if the owner or operator of the unit:
(1) Notifies the Administrator of an exemption claim; and
(2) Provides data documenting that the unit qualifies for this
exemption.
(d) Any cofired combustor, as defined under Sec. 60.51a, located at
a plant that meets the capacity specifications in paragraph (a) of this
section is not subject to this subpart if the owner or operator of the
cofired combustor:
(1) Notifies the Administrator of an exemption claim;
(2) Provides a copy of the federally enforceable permit (specified
in the definition of cofired combustor in this section); and
[[Page 148]]
(3) Keeps a record on a calendar quarter basis of the weight of
municipal solid waste combusted at the cofired combustor and the weight
of all other fuels combusted at the cofired combustor.
(e) Any cofired combustor that is subject to a federally enforceable
permit limiting the operation of the combustor to no more than 225
megagrams per day (250 tons per day) of municipal solid waste is not
subject to this subpart.
(f) Physical or operational changes made to an existing municipal
waste combustor unit primarily for the purpose of complying with
emission guidelines under subpart Cb are not considered a modification
or reconstruction and do not result in an existing municipal waste
combustor unit becoming subject to this subpart.
(g) A qualifying small power production facility, as defined in
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that
burns homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy is
not subject to this subpart if the owner or operator of the facility
notifies the Administrator of an exemption claim and provides data
documenting that the facility qualifies for this exemption.
(h) A qualifying cogeneration facility, as defined in section
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns
homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy and
steam or forms of useful energy (such as heat) that are used for
industrial, commercial, heating, or cooling purposes, is not subject to
this subpart if the owner or operator of the facility notifies the
Administrator of an exemption claim and provides data documenting that
the facility qualifies for this exemption.
(i) Any unit required to have a permit under section 3005 of the
Solid Waste Disposal Act is not subject to this subpart.
(j) Any materials recovery facility (including primary or secondary
smelters) that combusts waste for the primary purpose of recovering
metals is not subject to this subpart.
(k) Pyrolysis/combustion units that are an integrated part of a
plastics/rubber recycling unit (as defined in Sec. 60.51a) are not
subject to this subpart if the owner or operator of the plastics/rubber
recycling unit keeps records of: the weight of plastics, rubber, and/or
rubber tires processed on a calendar quarter basis; the weight of
chemical plant feedstocks and petroleum refinery feedstocks produced and
marketed on a calendar quarter basis; and the name and address of the
purchaser of the feedstocks. The combustion of gasoline, diesel fuel,
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke,
liquified petroleum gas, propane, or butane produced by chemical plants
or petroleum refineries that use feedstocks produced by plastics/rubber
recycling units are not subject to this subpart.
(l) The following authorities shall be retained by the Administrator
and not transferred to a State:
None.
(m) This subpart shall become effective on August 12, 1991.
[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65384, Dec. 19, 1995]
Sec. 60.51a Definitions.
ASME means the American Society of Mechanical Engineers.
Batch MWC means an MWC unit designed such that it cannot combust MSW
continuously 24 hours per day because the design does not allow waste to
be fed to the unit or ash to be removed while combustion is occurring.
Bubbling fluidized bed combustor means a fluidized bed combustor in
which the majority of the bed material remains in a fluidized state in
the primary combustion zone.
Calendar quarter means a consecutive 3-month period (nonoverlapping)
beginning on January 1, April 1, July 1, and October 1.
Chief facility operator means the person in direct charge and
control of the operation of an MWC and who is responsible for daily on-
site supervision, technical direction, management, and overall
performance of the facility.
Circulating fluidized bed combustor means a fluidized bed combustor
in
[[Page 149]]
which the majority of the fluidized bed material is carried out of the
primary combustion zone and is transported back to the primary zone
through a recirculation loop.
Clean wood means untreated wood or untreated wood products including
clean untreated lumber, tree stumps (whole or chipped), and tree limbs
(whole or chipped). Clean wood does not include yard waste, which is
defined elsewhere in this section, or construction, renovation, and
demolition wastes (which includes but is not limited to railroad ties
and telephone poles), which are exempt from the definition of municipal
solid waste in this section.
Cofired combustor means a unit combusting municipal solid waste with
nonmunicipal solid waste fuel (e.g., coal, industrial process waste) and
subject to a federally enforceable permit limiting the unit to
combusting a fuel feed stream, 30 percent or less of the weight of which
is comprised, in aggregate, of municipal solid waste as measured on a
calendar quarter basis.
Continuous emission monitoring system or CEMS means a monitoring
system for continuously measuring the emissions of a pollutant from an
affected facility.
Continuous monitoring system means the total equipment used to
sample and condition (if applicable), to analyze, and to provide a
permanent record of emissions or process parameters.
Dioxin/furan means total tetra- through octachlorinated dibenzo-p-
dioxins and dibenzofurans.
Federally-enforceable means all limitations and conditions that are
enforceable by the Administrator including the requirements of 40 CFR
parts 60 and 61, requirements within any applicable State implementation
plan, and any permit requirements established under 40 CFR 52.21 or
under 40 CFR 51.18 and 40 CFR 51.24.
Four-hour block average or 4-hour block average means the average of
all hourly emission rates when the affected facility is operating and
combusting MSW measured over 4-hour periods of time from 12 midnight to
4 a.m., 4 a.m. to 8 a.m., 8 a.m. to 12 noon, 12 noon to 4 p.m., 4 p.m.
to 8 p.m., and 8 p.m. to 12 midnight.
Large municipal waste combustor plant means a municipal waste
combustor plant with a municipal waste combustor aggregate plant
capacity for affected facilities that is greater than 225 megagrams per
day (250 tons per day) of municipal solid waste.
Mass burn refractory municipal waste combustor means a field-erected
combustor that combusts municipal solid waste in a refractory wall
furnace. Unless otherwise specified, this includes combustors with a
cylindrical rotary refractory wall furnace.
Mass burn rotary waterwall municipal waste combustor means a field-
erected combustor that combusts municipal solid waste in a cylindrical
rotary waterwall furnace.
Mass burn waterwall municipal waste combustor means a field-erected
combustor that combusts municipal solid waste in a waterwall furnace.
Maximum demonstrated municipal waste combustor unit load means the
highest 4-hour arithmetic average municipal waste combustor unit load
achieved during four consecutive hours during the most recent dioxin/
furan performance test demonstrating compliance with the applicable
limit for municipal waste combustor organics specified under
Sec. 60.53a.
Maximum demonstrated particulate matter control device temperature
means the highest 4-hour arithmetic average flue gas temperature
measured at the particulate matter control device inlet during four
consecutive hours during the most recent dioxin/furan performance test
demonstrating compliance with the applicable limit for municipal waste
combustor organics specified under Sec. 60.53a.
Modification or modified municipal waste combustor unit means a
municipal waste combustor unit to which changes have been made if the
cumulative cost of the changes, over the life of the unit, exceed 50
percent of the original cost of construction and installation of the
unit (not including the cost of any land purchased in connection with
such construction or installation) updated to current costs; or any
physical change in the municipal waste combustor unit or change in the
method of operation of
[[Page 150]]
the municipal waste combustor unit increases the amount of any air
pollutant emitted by the unit for which standards have been established
under section 129 or section 111. Increases in the amount of any air
pollutant emitted by the municipal waste combustor unit are determined
at 100-percent physical load capability and downstream of all air
pollution control devices, with no consideration given for load
restrictions based on permits or other nonphysical operational
restrictions.
Modular excess air MWC means a combustor that combusts MSW and that
is not field-erected and has multiple combustion chambers, all of which
are designed to operate at conditions with combustion air amounts in
excess of theoretical air requirements.
Modular starved air MWC means a combustor that combusts MSW and that
is not field-erected and has multiple combustion chambers in which the
primary combustion chamber is designed to operate at substoichiometric
conditions.
Municipal solid waste or municipal-type solid waste or MSW means
household, commercial/retail, and/or institutional waste. Household
waste includes material discarded by single and multiple residential
dwellings, hotels, motels, and other similar permanent or temporary
housing establishments or facilities. Commercial/retail waste includes
material discarded by stores, offices, restaurants, warehouses,
nonmanufacturing activities at industrial facilities, and other similar
establishments or facilities. Institutional waste includes material
discarded by schools, nonmedical waste discarded by hospitals, material
discarded by nonmanufacturing activities at prisons and government
facilities, and material discarded by other similar establishments or
facilities. Household, commercial/retail, and institutional waste does
not include used oil; sewage sludge; wood pallets; construction,
renovation, and demolition wastes (which includes but is not limited to
railroad ties and telephone poles); clean wood; industrial process or
manufacturing wastes; medical waste; or motor vehicles (including motor
vehicle parts or vehicle fluff). Household, commercial/retail, and
institutional wastes include:
(1) Yard waste;
(2) Refuse-derived fuel; and
(3) Motor vehicle maintenance materials limited to vehicle batteries
and tires except as specified in Sec. 60.50a(c).
Municipal waste combustor, MWC, or municipal waste combustor unit:
(1) Means any setting or equipment that combusts solid, liquid, or
gasified MSW including, but not limited to, field-erected incinerators
(with or without heat recovery), modular incinerators (starved-air or
excess-air), boilers (i.e., steam-generating units), furnaces (whether
suspension-fired, grate-fired, mass-fired, air curtain incinerators, or
fluidized bed-fired), and pyrolysis/combustion units. Municipal waste
combustors do not include pyrolysis/combustion units located at
plastics/ rubber recycling units (as specified in Sec. 60.50a(k) of this
section). Municipal waste combustors do not include internal combustion
engines, gas turbines, or other combustion devices that combust landfill
gases collected by landfill gas collection systems.
(2) The boundaries of an MWC are defined as follows. The MWC unit
includes, but is not limited to, the MSW fuel feed system, grate system,
flue gas system, bottom ash system, and the combustor water system. The
MWC boundary starts at the MSW pit or hopper and extends through:
(i) The combustor flue gas system, which ends immediately following
the heat recovery equipment or, if there is no heat recovery equipment,
immediately following the combustion chamber;
(ii) The combustor bottom ash system, which ends at the truck
loading station or similar ash handling equipment that transfer the ash
to final disposal, including all ash handling systems that are connected
to the bottom ash handling system; and
(iii) The combustor water system, which starts at the feed water
pump and ends at the piping exiting the steam drum or superheater.
(3) The MWC unit does not include air pollution control equipment,
the stack, water treatment equipment, or the turbine generator set.
[[Page 151]]
Municipal waste combustor plant means one or more MWC units at the
same location for which construction, modification, or reconstruction is
commenced after December 20, 1989 and on or before September 20, 1994.
Municipal waste combustor plant capacity means the aggregate MWC
unit capacity of all MWC units at an MWC plant for which construction,
modification, or reconstruction of the units commenced after December
20, 1989 and on or before September 20, 1994. Any MWC units for which
construction, modification, or reconstruction is commenced on or before
December 20, 1989 or after September 20, 1994 are not included for
determining applicability under this subpart.
Municipal waste combustor unit capacity means the maximum design
charging rate of an MWC unit expressed in megagrams per day (tons per
day) of MSW combusted, calculated according to the procedures under
Sec. 60.58a(j). Municipal waste combustor unit capacity is calculated
using a design heating value of 10,500 kilojoules per kilogram (4,500
British thermal units per pound) for MSW. The calculational procedures
under Sec. 60.58a(j) include procedures for determining MWC unit
capacity for continuous and batch feed MWC's.
Municipal waste combustor unit load means the steam load of the MWC
unit measured as specified in Sec. 60.58a(h)(6).
MWC acid gases means all acid gases emitted in the exhaust gases
from MWC units including, but not limited to, sulfur dioxide and
hydrogen chloride gases.
MWC metals means metals and metal compounds emitted in the exhaust
gases from MWC units.
MWC organics means organic compounds emitted in the exhaust gases
from MWC units and includes total tetra- through octa-chlorinated
dibenzo-p-dioxins and dibenzofurans.
Particulate matter means total particulate matter emitted from MWC
units as measured by Method 5 (see Sec. 60.58a).
Plastics/rubber recycling unit means an integrated processing unit
where plastics, rubber, and/or rubber tires are the only feed materials
(incidental contaminants may be included in the feed materials) and they
are processed into a chemical plant feedstock or petroleum refinery
feedstock, where the feedstock is marketed to and used by a chemical
plant or petroleum refinery as input feedstock. The combined weight of
the chemical plant feedstock and petroleum refinery feedstock produced
by the plastics/rubber recycling unit on a calendar quarter basis shall
be more than 70 percent of the combined weight of the plastics, rubber,
and rubber tires processed by the plastics/rubber recycling unit on a
calendar quarter basis. The plastics, rubber, and/or rubber tire feed
materials to the plastics/rubber recycling unit may originate from the
separation or diversion of plastics, rubber, or rubber tires from MSW or
industrial solid waste, and may include manufacturing scraps, trimmings,
and off-specification plastics, rubber, and rubber tire discards. The
plastics, rubber, and rubber tire feed materials to the plastics/rubber
recycling unit may contain incidental contaminants (e.g., paper labels
on plastic bottles, metal rings on plastic bottle caps, etc.).
Potential hydrogen chloride emission rate means the hydrogen
chloride emission rate that would occur from combustion of MSW in the
absence of any hydrogen chloride emissions control.
Potential sulfur dioxide emission rate means the sulfur dioxide
emission rate that would occur from combustion of MSW in the absence of
any sulfur dioxide emissions control.
Pulverized coal/refuse-derived fuel mixed fuel-fired combustor or
pulverized coal/RDF mixed fuel-fired combustor means a combustor that
fires coal and RDF simultaneously, in which pulverized coal is
introduced into an air stream that carries the coal to the combustion
chamber of the unit where it is fired in suspension. This includes both
conventional pulverized coal and micropulverized coal.
Pyrolysis/combustion unit means a unit that produces gases, liquids,
or solids through the heating of MSW, and the gases, liquids, or solids
produced are combusted and emissions vented to the atmosphere.
Reconstruction means rebuilding an MWC unit for which the cumulative
costs of the construction over the life of the unit exceed 50 percent of
the
[[Page 152]]
original cost of construction and installation of the unit (not
including any cost of land purchased in connection with such
construction or installation) updated to current costs (current
dollars).
Refractory unit or refractory wall furnace means a combustion unit
having no energy recovery (e.g., via a waterwall) in the furnace (i.e.,
radiant heat transfer section) of the combustor.
Refuse-derived fuel or RDF means a type of MSW produced by
processing MSW through shredding and size classification.
This includes all classes of RDF including low density fluff RDF
through densified RDF and RDF fuel pellets.
RDF stoker means a steam generating unit that combusts RDF in a
semi-suspension firing mode using air-fed distributors.
Same location means the same or contiguous property that is under
common ownership or control, including properties that are separated
only by a street, road, highway, or other public right-of-way. Common
ownership or control includes properties that are owned, leased, or
operated by the same entity, parent entity, subsidiary, subdivision, or
any combination thereof, including any municipality or other
governmental unit, or any quasigovernmental authority (e.g., a public
utility district or regional waste disposal authority).
Shift supervisor means the person in direct charge and control of
the operation of an MWC and who is responsible for on-site supervision,
technical direction, management, and overall performance of the facility
during an assigned shift.
Spreader stoker coal/refuse-derived fuel mixed fuel-fired combustor
or spreader stoker coal/RDF mixed fuel-fired combustor means a combustor
that fires coal and refuse-derived fuel simultaneously, in which coal is
introduced to the combustion zone by a mechanism that throws the fuel
onto a grate from above. Combustion takes place both in suspension and
on the grate.
Standard conditions means a temperature of 20 deg.C (68 deg.F) and
a pressure of 101.3 kilopascals (29.92 inches of mercury).
Twenty-four hour daily average or 24-hour daily average means the
arithmetic or geometric mean (as specified in Sec. 60.58a (e), (g), or
(h) as applicable) of all hourly emission rates when the affected
facility is operating and firing MSW measured over a 24-hour period
between 12 midnight and the following midnight.
Untreated lumber means wood or wood products that have been cut or
shaped and include wet, air-dried, and kiln-dried wood products.
Untreated lumber does not include wood products that have been painted,
pigment-stained, or ``pressure-treated.'' Pressure-treating compounds
include, but are not limited to, chromate copper arsenate,
pentachlorophenol, and creosote.
Waterwall furnace means a combustion unit having energy (heat)
recovery in the furnace (i.e., radiant heat transfer section) of the
combustor.
Yard waste means grass, grass clippings, bushes, shrubs, and
clippings from bushes and shrubs that are generated by residential,
commercial/retail, institutional, and/or industrial sources as part of
maintenance activities associated with yards or other private or public
lands. Yard waste does not include construction, renovation, and
demolition wastes, which are exempt from the definition of MSW in this
section. Yard waste does not include clean wood, which is exempt from
the definition of MSW in this section.
[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65384, Dec. 19, 1995; 65
FR 61753, Oct. 17, 2000]
Sec. 60.52a Standard for municipal waste combustor metals.
(a) On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain particulate matter in excess of 34 milligrams per
dry standard cubic meter (0.015 grains per dry standard cubic foot),
corrected to 7 percent oxygen (dry basis).
(b) On and after the date on which the initial compliance test is
completed or is required to be completed
[[Page 153]]
under Sec. 60.8, no owner or operator of an affected facility subject to
the particulate matter emission limit under paragraph (a) of this
section shall cause to be discharged into the atmosphere from that
affected facility any gases that exhibit greater than 10 percent opacity
(6-minute average).
(c) [Reserved]
Sec. 60.53a Standard for municipal waste combustor organics.
(a) [Reserved]
(b) On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain dioxin/furan emissions that exceed 30 nanograms
per dry standard cubic meter (12 grains per billion dry standard cubic
feet), corrected to 7 percent oxygen (dry basis).
Sec. 60.54a Standard for municipal waste combustor acid gases.
(a)--(b) [Reserved]
(c) On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain sulfur dioxide in excess of 20 percent of the
potential sulfur dioxide emission rate (80 percent reduction by weight
or volume) or 30 parts per million by volume, corrected to 7 percent
oxygen (dry basis), whichever is less stringent. The averaging time is
specified in Sec. 60.58a(e).
(d) On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain hydrogen chloride in excess of 5 percent of the
potential hydrogen chloride emission rate (95 percent reduction by
weight or volume) or 25 parts per million by volume, corrected to 7
percent oxygen (dry basis), whichever is less stringent.
Sec. 60.55a Standard for nitrogen oxides.
On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause to be discharged into the atmosphere from that affected facility
any gases that contain nitrogen oxides in excess of 180 parts per
million by volume, corrected to 7 percent oxygen (dry basis). The
averaging time is specified under Sec. 60.58a(g).
Sec. 60.56a Standards for municipal waste combustor operating practices.
(a) On and after the date on which the initial compliance test is
completed or is required to be completed under Sec. 60.8, no owner or
operator of an affected facility located within a large MWC plant shall
cause such facility to exceed the carbon monoxide standards shown in
table 1.
Table 1--MWC Operating Standards
------------------------------------------------------------------------
Carbon
monoxide
emission limit
MWC technology (parts per
million by
volume) \1\
------------------------------------------------------------------------
Mass burn waterwall..................................... 100
Mass burn refractory.................................... 100
Mass burn rotary waterwall.............................. 100
Modular starved air..................................... 50
Modular excess air...................................... 50
RDF stoker.............................................. 150
Bubbling fluidized bed combustor........................ 100
Circulating fluidized bed combustor..................... 100
Pulverized coal/RDF mixed fuel-fired combustor.......... 150
Spreader stoker coal/RDF mixed fuel-fird combustor...... 150
------------------------------------------------------------------------
\1\ Measured at the combustor outlet in conjunction with a measurement
of oxygen concentration, corrected to 7 percent oxygen (dry basis).
The averaging times are specified in Sec. 60.58a(h).
(b) No owner or operator of an affected facility located within a
large MWC plant shall cause such facility to operate at a load level
greater than 110 percent of the maximum demonstrated MWC unit load as
defined in Sec. 60.51a. The averaging time is specified under
Sec. 60.58a(h).
(c) No owner or operator of an affected facility located within a
large MWC plant shall cause such facility to operate at a temperature,
measured at
[[Page 154]]
the final particulate matter control device inlet, exceeding 17
deg.Centigrade (30 deg.Fahrenheit) above the maximum demonstrated
particulate matter control device temperature as defined in Sec. 60.51a.
The averaging time is specified under Sec. 60.58a(h).
(d) Within 24 months from the date of start-up of an affected
facility or before February 11, 1993, whichever is later, each chief
facility operator and shift supervisor of an affected faciltiy located
within a large MWC plant shall obtain and keep current either a
provisional or operator certification in accordance with ASME QRO-1-1994
(incorporated by reference, see Sec. 60.17) or an equivalent State-
approved certification program.
(e) No owner or operator of an affected facility shall allow such
affected facility located at a large MWC plant to operate at any time
without a certified shift supervisor, as provided under paragraph (d) of
this section, on duty at the affected facility. This requirement shall
take effect 24 months after the date of start-up of the affected
facility or on and after February 11, 1993, whichever is later.
(f) The owner or operator of an affected facility located within a
large MWC plant shall develop and update on a yearly basis a
sitespecific operating manual that shall, at a minimum, address the
following elements of MWC unit operation:
(1) Summary of the applicable standards under this subpart;
(2) Description of basic combustion theory applicable to an MWC
unit;
(3) Procedures for receiving, handling, and feeding MSW;
(4) MWC unit start-up, shutdown, and malfunction procedures;
(5) Procedures for maintaining proper combustion air supply levels;
(6) Procedures for operating the MWC unit within the standards
established under this subpart;
(7) Procedures for responding to periodic upset or off-specification
conditions;
(8) Procedures for minimizing particulate matter carryover;
(9) [Reserved]
(10) Procedures for handling ash;
(11) Procedures for monitoring MWC unit emissions; and
(12) Reporting and recordkeeping procedures.
(g) The owner or operator of an affected facility located within a
large MWC plant shall establish a program for reviewing the operating
manual annually with each person who has responsibilities affecting the
operation of an affected facility including, but not limited to, chief
facility operators, shift supervisors, control room operators, ash
handlers, maintenance personnel, and crane/load handlers.
(h) The initial review of the operating manual, as specified under
paragraph (g) of this section, shall be conducted prior to assumption of
responsibilities affecting MWC unit operation by any person required to
undergo training under paragraph (g) of this section. Subsequent reviews
of the manual shall be carried out annually by each such person.
(i) The operating manual shall be kept in a readily accessible
location for all persons required to undergo training under paragraph
(g) of this section. The operating manual and records of training shall
be available for inspection by EPA or its delegated enforcement agent
upon request.
(j)--(k) [Reserved]
[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65386, Dec. 19, 1995]
Sec. 60.57a [Reserved]
Sec. 60.58a Compliance and performance testing.
(a) The standards under this subpart apply at all times, except
during periods of start-up, shutdown, or malfunction; provided, however,
that the duration of start-up, shutdown, or malfunction shall not exceed
3 hours per occurrence.
(1) The start-up period commences when the affected facility begins
the continuous burning of MSW and does not include any warm-up period
when the affected facility is combusting only a fossil fuel or other
non-MSW fuel and no MSW is being combusted.
(2) Continuous burning is the continuous, semicontinuous, or batch
feeding of MSW for purposes of waste disposal, energy production, or
providing heat to the combustion system in preparation
[[Page 155]]
for waste disposal or energy production. The use of MSW solely to
provide thermal protection of grate or hearth during the start-up period
shall not be considered to be continuous burning.
(b) The following procedures and test methods shall be used to
determine compliance with the emission limits for particulate matter
under Sec. 60.52a:
(1) Method 1 shall be used to select sampling site and number of
traverse points.
(2) Method 3 shall be used for gas analysis.
(3) Method 5 shall be used for determining compliance with the
particulate matter emission limit. The minimum sample volume shall be
1.7 cubic meters (60 cubic feet). The probe and filter holder heating
systems in the sample train shall be set to provide a gas temperature of
160 deg.14 deg.Centigrade (320 deg.25
deg.Fahrenheit). An oxygen or carbon dioxide measurement shall be
obtained simultaneously with each Method 5 run.
(4) For each Method 5 run, the emission rate shall be determined
using:
(i) Oxygen or carbon dioxide measurements,
(ii) Dry basis F factor, and
(iii) Dry basis emission rate calculation procedures in Method 19.
(5) An owner or operator may request that compliance be determined
using carbon dioxide measurements corrected to an equivalent of 7
percent oxygen. The relationship between oxygen and carbon dioxide
levels for the affected facility shall be established during the initial
compliance test.
(6) The owner or operator of an affected facility shall conduct an
initial compliance test for particulate matter and opacity as required
under Sec. 60.8.
(7) Method 9 shall be used for determining compliance with the
opacity limit.
(8) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous opacity monitoring system
(COMS) and record the output of the system on a 6-minute average basis.
(9) Following the date the initial compliance test for particulate
matter is completed or is required to be completed under Sec. 60.8 for
an affected facility located within a large MWC plant, the owner or
operator shall conduct a performance test for particulate matter on an
annual basis (no more than 12 calendar months following the previous
compliance test).
(10) [Reserved]
(c) [Reserved]
(d) The following procedures and test methods shall be used to
determine compliance with the limits for dioxin/furan emissions under
Sec. 60.53a:
(1) Method 23 shall be used for determining compliance with the
dioxin/furan emission limits. The minimum sample time shall be 4 hours
per test run.
(2) The owner or operator of an affected facility shall conduct an
initial compliance test for dioxin/furan emissions as required under
Sec. 60.8.
(3) Following the date of the initial compliance test or the date on
which the initial compliance test is required to be completed under
Sec. 60.8, the owner or operator of an affected facility located within
a large MWC plant shall conduct a performance test for dioxin/furan
emissions on an annual basis (no more than 12 calendar months following
the previous compliance test).
(4) [Reserved]
(5) An owner or operator may request that compliance with the
dioxin/furan emissions limit be determined using carbon dioxide
measurements corrected to an equivalent of 7 percent oxygen. The
relationship between oxygen and carbon dioxide levels for the affected
facility shall be established during the initial compliance test.
(e) The following procedures and test methods shall be used for
determining compliance with the sulfur dioxide limit under Sec. 60.54a:
(1) Method 19, section 5.4, shall be used to determine the daily
geometric average percent reduction in the potential sulfur dioxide
emission rate.
(2) Method 19, section 4.3, shall be used to determine the daily
geometric average sulfur dioxide emission rate.
(3) An owner or operator may request that compliance with the sulfur
dioxide emissions limit be determined using carbon dioxide measurements
corrected to an equivalent of 7 percent oxygen. The relationship between
oxygen
[[Page 156]]
and carbon dioxide levels for the affected facility shall be established
during the initial compliance test.
(4) The owner or operator of an affected facility shall conduct an
initial compliance test for sulfur dioxide as required under Sec. 60.8.
Compliance with the sulfur dioxide emission limit and percent reduction
is determined by using a CEMS to measure sulfur dioxide and calculating
a 24-hour daily geometric mean emission rate and daily geometric mean
percent reduction using Method 19 sections 4.3 and 5.4, as applicable,
except as provided under paragraph (e)(5) of this section.
(5) For batch MWC's or MWC units that do not operate continuously,
compliance shall be determined using a daily geometric mean of all
hourly average values for the hours during the day that the affected
facility is combusting MSW.
(6) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a CEMS for measuring sulfur dioxide
emissions discharged to the atmosphere and record the output of the
system.
(7) Following the date of the initial compliance test or the date on
which the initial compliance test is required to be completed under
Sec. 60.8, compliance with the sulfur dioxide emission limit or percent
reduction shall be determined based on the geometric mean of the hourly
arithmetic average emission rates during each 24-hour daily period
measured between 12:00 midnight and the following midnight using: CEMS
inlet and outlet data, if compliance is based on a percent reduction; or
CEMS outlet data only if compliance is based on an emission limit.
(8) At a minimum, valid CEMS data shall be obtained for 75 percent
of the hours per day for 75 percent of the days per month the affected
facility is operated and combusting MSW.
(9) The 1-hour arithmetic averages required under paragraph (e)(7)
of this section shall be expressed in parts per million (dry basis) and
used to calculate the 24-hour daily geometric mean emission rates. The
1-hour arithmetic averages shall be calculated using the data points
required under Sec. 60.13(e)(2). At least two data points shall be used
to calculate each 1-hour arithmetic average.
(10) All valid CEMS data shall be used in calculating emission rates
and percent reductions even if the minimum CEMS data requirements of
paragraph (e)(8) of this section are not met.
(11) The procedures under Sec. 60.1 3 shall be followed for
installation, evaluation, and operation of the CEMS.
(12) The CEMS shall be operated according to Performance
Specifications 1, 2, and 3 (appendix B of part 60).
(13) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with Procedure 1 (appendix F of
part 60).
(14) The span value of the CEMS at the inlet to the sulfur dioxide
control device is 125 percent of the maximum estimated hourly potential
sulfur dioxide emissions of the MWC unit, and the span value of the CEMS
at the outlet of the sulfur dioxide control device is 50 percent of the
maximum estimated hourly potential sulfur dioxide emissions of the MWC
unit.
(15) When sulfur dioxide emissions data are not obtained because of
CEMS breakdowns, repairs, calibration checks and zero and span
adjustments, emissions data shall be obtained by using other monitoring
systems as approved by the Administrator or Method 19 to provide as
necessary valid emission data for a minimum of 75 percent of the hours
per day for 75 percent of the days per month the unit is operated and
combusting MSW.
(16) Not operating a sorbent injection system for the sole purpose
of testing in order to demonstrate compliance with the percent reduction
standards for MWC acid gases shall not be considered a physical change
in the method of operation under 40 CFR 52.21, or under regulations
approved pursuant to 40 CFR 51.166 or 40 CFR 51.165 (a) and (b).
(f) The following procedures and test methods shall be used for
determining compliance with the hydrogen chloride limits under
Sec. 60.54a:
(1) The percentage reduction in the potential hydrogen chloride
emissions (%PHCl) is computed using the following formula:
[[Page 157]]
[GRAPHIC] [TIFF OMITTED] TC16NO91.003
where:
Ei is the potential hydrogen chloride emission rate.
Eo is the hydrogen chloride emission rate measured at the
outlet of the acid gas control device.
(2) Method 26 or 26A shall be used for determining the hydrogen
chloride emission rate. The minimum sampling time for Method 26 or 26A
shall be 1 hour.
(3) An owner or operator may request that compliance with the
hydrogen chloride emissions limit be determined using carbon dioxide
measurements corrected to an equivalent of 7 percent oxygen. The
relationship between oxygen and carbon dioxide levels for the affected
facility shall be established during the initial compliance test.
(4) The owner or operator of an affected facility shall conduct an
initial compliance test for hydrogen chloride as required under
Sec. 60.8.
(5) Following the date of the initial compliance test or the date on
which the initial compliance test is required under Sec. 60.8, the owner
or operator of an affected facility located within a large MWC plant
shall conduct a performance test for hydrogen chloride on an annual
basis (no more than 12 calendar months following the previous compliance
test).
(6) [Reserved]
(7) Not operating a sorbent injection system for the sole purpose of
testing in order to demonstrate compliance with the percent reduction
standards for MWC acid gases shall not be considered a physical change
in the method of operation under 40 CFR 52.21, or under regulations
approved pursuant to 40 CFR 51.166 or 40 CFR 51.165 (a) and (b).
(g) The following procedures and test methods shall be used to
determine compliance with the nitrogen oxides limit under Sec. 60.55a:
(1) Method 19, section 4.1, shall be used for determining the daily
arithmetic average nitrogen oxides emission rate.
(2) An owner or operator may request that compliance with the
nitrogen oxides emissions limit be determined using carbon dioxide
measurements corrected to an equivalent of 7 percent oxygen. The
relationship between oxygen and carbon dioxide levels for the affected
facility shall be established during the initial compliance test.
(3) The owner or operator of an affected facility subject to the
nitrogen oxides limit under Sec. 60.55a shall conduct an initial
compliance test for nitrogen oxides as required under Sec. 60.8.
Compliance with the nitrogen oxides emission standard shall be
determined by using a CEMS for measuring nitrogen oxides and calculating
a 24-hour daily arithmetic average emission rate using Method 19,
section 4.1, except as specified under paragraph (g)(4) of this section.
(4) For batch MWC's or MWC's that do not operate continuously,
compliance shall be determined using a daily arithmetic average of all
hourly average values for the hours during the day that the affected
facility is combusting MSW.
(5) The owner or operator of an affected facility subject to the
nitrogen oxides emissions limit under Sec. 60.55a shall install,
calibrate, maintain, and operate a CEMS for measuring nitrogen oxides
discharged to the atmosphere and record the output of the system.
(6) Following the initial compliance test or the date on which the
initial compliance test is required to be completed under Sec. 60.8,
compliance with the emission limit for nitrogen oxides required under
Sec. 60.55a shall be determined based on the arithmetic average of the
arithmetic average hourly emission rates during each 24-hour daily
period measured between 12:00 midnight and the following midnight using
CEMS data.
(7) At a minimum valid CEMS data shall be obtained for 75 percent of
the hours per day for 75 percent of the days per month the affected
facility is operated and combusting MSW.
(8) The 1-hour arithmetic averages required by paragraph (g)(6) of
this section shall be expressed in parts per million volume (dry basis)
and used to calculate the 24-hour daily arithmetic average emission
rates. The 1-hour arithmetic averages shall be calculated using the data
points required under
[[Page 158]]
Sec. 60.13(b). At least two data points shall be used to calculate each
1-hour arithmetic average.
(9) All valid CEMS data must be used in calculating emission rates
even if the minimum CEMS data requirements of paragraph (g)(7) of this
section are not met.
(10) The procedures under Sec. 60.13 shall be followed for
installation, evaluation, and operation of the CEMS.
(11) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with Procedure 1 (appendix F of
part 60).
(12) When nitrogen oxides emissions data are not obtained because of
CEMS breakdowns, repairs, calibration checks, and zero and span
adjustments, emission data calculations to determine compliance shall be
made using other monitoring systems as approved by the Administrator or
Method 19 to provide as necessary valid emission data for a minimum of
75 percent of the hours per day for 75 percent of the days per month the
unit is operated and combusting MSW.
(h) The following procedures shall be used for determining
compliance with the operating standards under Sec. 60.56a:
(1) Compliance with the carbon monoxide emission limits in
Sec. 60.56a(a) shall be determined using a 4-hour block arithmetic
average for all types of affected facilities except mass burn rotary
waterwall MWC's, RDF stokers, and spreader stoker/RDF mixed fuel-fired
combustors.
(2) For affected mass burn rotary waterwall MWC's, RDF stokers, and
spreader stoker/RDF mixed fuel-fired combustors, compliance with the
carbon monoxide emission limits in Sec. 60.56a(a) shall be determined
using a 24-hour daily arithmetic average.
(3) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a CEMS for measuring carbon monoxide at
the combustor outlet and record the output of the system.
(4) The 4-hour and 24-hour daily arithmetic averages in paragraphs
(h) (1) and (2) of this section shall be calculated from 1-hour
arithmetic averages expressed in parts per million by volume (dry
basis). The 1-hour arithmetic averages shall be calculated using the
data points generated by the CEMS. At least two data points shall be
used to calculate each 1-hour arithmetic average.
(5) An owner or operator may request that compliance with the carbon
monoxide emission limit be determined using carbon dioxide measurements
corrected to an equivalent of 7 percent oxygen. The relationship between
oxygen and carbon dioxide levels for the affected facility shall be
established during the initial compliance test.
(6) The following procedures shall be used to determine compliance
with load level requirements under Sec. 60.56a(b):
(i) The owner or operator of an affected facility with steam
generation capability shall install, calibrate, maintain, and operate a
steam flow meter or a feedwater flow meter; measure steam or feedwater
flow in kilograms per hour (pounds per hour) on a continuous basis; and
record the output of the monitor. Steam or feedwater flow shall be
calculated in 4-hour block arithmetic averages.
(ii) The method included in ``American Society of Mechanical
Engineers Power Test Codes: Test Code for Steam Generating Units, Power
Test Code 4.1--1964'', Section 4 (incorporated by reference, see
Sec. 60.17) shall be used for calculating the steam (or feedwater flow)
required under paragraph (h)(6)(i) of this section. The recommendations
of ``American Society of Mechanical Engineers Interim Supplement 19.5 on
Instruments and Apparatus: Application, Part II of Fluid Meters, 6th
edition (1971),'' chapter 4 (incorporated by reference, see Sec. 60.17)
shall be followed for design, construction, installation, calibration,
and use of nozzles and orifices except as specified in (h)(6)(iii) of
this section.
(iii) Measurement devices such as flow nozzles and orifices are not
required to be recalibrated after they are installed.
(iv) All signal conversion elements associated with steam (or
feedwater flow) measurements must be calibrated according to the
manufacturer's instructions before each dioxin/furan compliance and
performance test, and at least once per year.
[[Page 159]]
(v) The owner or operator of an affected facility without heat
recovery shall:
(A) [Reserved]
(7) To determine compliance with the maximum particulate matter
control device temperature requirements under Sec. 60.56a(c), the owner
or operator of an affected facility shall install, calibrate, maintain,
and operate a device for measuring temperature of the flue gas stream at
the inlet to the final particulate matter control device on a continuous
basis and record the output of the device. Temperature shall be
calculated in 4-hour block arithmetic averages.
(8) Maximum demonstrated MWC unit load shall be determined during
the initial compliance test for dioxins/furans and each subsequent
performance test during which compliance with the dioxin/furan emission
limit under Sec. 60.53a is achieved. Maximum demonstrated MWC unit load
shall be the maximum 4-hour arithmetic average load achieved during the
most recent test during which compliance with the dioxin/furan limit was
achieved.
(9) The maximum demonstrated particulate matter control device
temperature shall be determined during the initial compliance test for
dioxins/furans and each subsequent performance test during which
compliance with the dioxin/furan emission limit under Sec. 60.53a is
achieved. Maximum demonstrated particulate matter control device
temperature shall be the maximum 4-hour arithmetic average temperature
achieved at the final particulate matter control device inlet during the
most recent test during which compliance with the dioxin/furan limit was
achieved.
(10) At a minimum, valid CEMS data for carbon monoxide, steam or
feedwater flow, and particulate matter control device inlet temperature
shall be obtained 75 percent of the hours per day for 75 percent of the
days per month the affected facility is operated and combusting MSW.
(11) All valid data must be used in calculating the parameters
specified under paragraph (h) of this section even if the minimum data
requirements of paragraph (h)(10) of this section are not met.
(12) Quarterly accuracy determinations and daily calibration drift
tests for carbon monoxide CEMS shall be performed in accordance with
Procedure 1 (appendix F).
(i) [Reserved]
(j) The following procedures shall be used for calculating MWC unit
capacity as defined under Sec. 60.51a:
(1) For MWC units capable of combusting MSW continuously for a 24-
hour period, MWC unit capacity, in megagrams per day (tons per day) of
MSW combusted, shall be calculated based on 24 hours of operation at the
maximum design charging rate. The design heating values under paragraph
(j)(4) of this section shall be used in calculating the design charging
rate.
(2) For batch MWC units, MWC unit capacity, in megagrams per day
(tons per day) of MSW combusted, shall be calculated as the maximum
design amount of MSW that can be charged per batch multiplied by the
maximum number of batches that could be processed in a 24-hour period.
The maximum number of batches that could be processed in a 24-hour
period is calculated as 24 hours divided by the design number of hours
required to process one batch of MSW, and may include fractional
batches.\1\ The design heating values under paragraph (j)(4) of this
section shall be used in calculating the MWC unit capacity in megagrams
per day (tons per day) of MSW.
---------------------------------------------------------------------------
\1\ For example, if one batch requires 16 hours, then 24/16, or 1.5
batches, could be combusted in a 24-hour period.
---------------------------------------------------------------------------
(3) [Reserved]
(4) The MWC unit capacity shall be calculated using a design heating
value of 10,500 kilojoules per kilogram (4,500 British thermal units per
pound) for all MSW.
[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65387, Dec. 19, 1995; 65
FR 61753, Oct. 17, 2000]
Sec. 60.59a Reporting and recordkeeping requirements.
(a) The owner or operator of an affected facility located at an MWC
plant with a capacity greater than 225 megagrams per day (250 tons per
day) shall provide notification of intent to construct and of planned
initial start-
[[Page 160]]
up date and the type(s) of fuels that they plan to combust in the
affected facility. The MWC unit capacity and MWC plant capacity and
supporting capacity calculations shall be provided at the time of the
notification of construction.
(b) The owner or operator of an affected facility located within a
small or large MWC plant and subject to the standards under Sec. 60.52a,
Sec. 60.53a, Sec. 60.54a, Sec. 60.55a, Sec. 60.56a, or Sec. 60.57a shall
maintain records of the following information for each affected facility
for a period of at least 2 years:
(1) Calendar date.
(2) The emission rates and parameters measured using CEMS as
specified under (b)(2) (i) and (ii) of this section:
(i) The following measurements shall be recorded in computer-
readable format and on paper:
(A) All 6-minute average opacity levels required under
Sec. 60.58a(b).
(B) All 1 hour average sulfur dioxide emission rates at the inlet
and outlet of the acid gas control device if compliance is based on a
percent reduction, or at the outlet only if compliance is based on the
outlet emission limit, as specified under Sec. 60.58a(e).
(C) All 1-hour average nitrogen oxides emission rates as specified
under Sec. 60.58a(g).
(D) All 1-hour average carbon monoxide emission rates, MWC unit load
measurements, and particulate matter control device inlet temperatures
as specified under Sec. 60.58a(h).
(ii) The following average rates shall be computed and recorded:
(A) All 24-hour daily geometric average percent reductions in sulfur
dioxide emissions and all 24-hour daily geometric average sulfur dioxide
emission rates as specified under Sec. 60.58a(e).
(B) All 24-hour daily arithmetic average nitrogen oxides emission
rates as specified under Sec. 60.58a(g).
(C) All 4-hour block or 24-hour daily arithmetic average carbon
monoxide emission rates, as applicable, as specified under
Sec. 60.58a(h).
(D) All 4-hour block arithmetic average MWC unit load levels and
particulate matter control device inlet temperatures as specified under
Sec. 60.58a(h).
(3) Identification of the operating days when any of the average
emission rates, percent reductions, or operating parameters specified
under paragraph (b)(2)(ii) of this section or the opacity level exceeded
the applicable limits, with reasons for such exceedances as well as a
description of corrective actions taken.
(4) Identification of operating days for which the minimum number of
hours of sulfur dioxide or nitrogen oxides emissions or operational data
(carbon monoxide emissions, unit load, particulate matter control device
temperature) have not been obtained, including reasons for not obtaining
sufficient data and a description of corrective actions taken.
(5) Identification of the times when sulfur dioxide or nitrogen
oxides emission or operational data (carbon monoxide emissions, unit
load, particulate matter control device temperature) have been excluded
from the calculation of average emission rates or parameters and the
reasons for excluding data.
(6) The results of daily sulfur dioxide, nitrogen oxides, and carbon
monoxide CEMS drift tests and accuracy assessments as required under
appendix F, Procedure 1.
(7) The results of all annual performance tests conducted to
determine compliance with the particulate matter, dioxin/furan and
hydrogen chloride limits. For all annual dioxin/furan tests, the maximum
demonstrated MWC unit load and maximum demonstrated particulate matter
control device temperature shall be recorded along with supporting
calculations.
(8)--(15) [Reserved]
(c) Following the initial compliance test as required under
Sec. Sec. 60.8 and 60.58a, the owner or operator of an affected facility
located within a large MWC plant shall submit the initial compliance
test data, the performance evaluation of the CEMS using the applicable
performance specifications in appendix B, and the maximum demonstrated
MWC unit load and maximum demonstrated particulate matter control device
temperature established during the dioxin/furan compliance test.
(d) [Reserved]
[[Page 161]]
(e)(1) The owner or operator of an affected facility located within
a large MWC plant shall submit annual compliance reports for sulfur
dioxide, nitrogen oxide (if applicable), carbon monoxide, load level,
and particulate matter control device temperature to the Administrator
containing the information recorded under paragraphs (b)(1), (2)(ii),
(4), (5), and (6) of this section for each pollutant or parameter. The
hourly average values recorded under paragraph (b)(2)(i) of this section
are not required to be included in the annual reports. Combustors firing
a mixture of medical waste and other MSW shall also provide the
information under paragraph (b)(15) of this section, as applicable, in
each annual report. The owner or operator of an affected facility must
submit reports semiannually once the affected facility is subject to
permitting requirements under Title V of the Act.
(2) The owner or operator shall submit a semiannual report for any
pollutant or parameter that does not comply with the pollutant or
parameter limits specified in this subpart. Such report shall include
the information recorded under paragraph (b)(3) of this section. For
each of the dates reported, include the sulfur dioxide, nitrogen oxide,
carbon monoxide, load level, and particulate matter control device
temperature data, as applicable, recorded under paragraphs (b)(2)(ii)(A)
through (D) of this section.
(3) Reports shall be postmarked no later than the 30th day following
the end of the annual or semiannual period, as applicable.
(f)(1) The owner or operator of an affected facility located within
a large MWC plant shall submit annual compliance reports, as applicable,
for opacity. The annual report shall list the percent of the affected
facility operating time for the reporting period that the opacity CEMS
was operating and collecting valid data. Once the unit is subject to
permitting requirements under Title V of the Act, the owner or operator
of an affected facility must submit these reports semiannually.
(2) The owner or operator shall submit a semiannual report for all
periods when the 6-minute average levels exceeded the opacity limit
under Sec. 60.52a. The semiannual report shall include all information
recorded under paragraph (b)(3) of this section which pertains to
opacity, and a listing of the 6-minute average opacity levels recorded
under paragraph (b)(2)(i)(A) of this section, which exceeded the opacity
limit.
(3) Reports shall be postmarked no later than the 30th day following
the end of the annual of semiannual period, as applicable.
(g)(1) The owner or operator of an affected facility located within
a large MWC plant shall submit reports to the Administrator of all
annual performance tests for particulate matter, dioxin/furan, and
hydrogen chloride as recorded under paragraph (b)(7) of this section, as
applicable, from the affected facility. For each annual dioxin/furan
compliance test, the maximum demonstrated MWC unit load and maximum
demonstrated particulate matter control device temperature shall be
reported. Such reports shall be submitted when available and in no case
later than the date of required submittal of the annual report specified
under paragraphs (e) and (f) of this section, or within six months of
the date the test was conducted, whichever is earlier.
(2) The owner or operator shall submit a report of test results
which document any particulate matter, dioxin/furan, and hydrogen
chloride levels that were above the applicable pollutant limit. The
report shall include a copy of the test report documenting the emission
levels and shall include the corrective action taken. Such reports shall
be submitted when available and in no case later than the date required
for submittal of any semiannual report required in paragraphs (e) or (f)
of this section, or within six months of the date the test was
conducted, whichever is earlier.
(h) [Reserved]
(i) Records of CEMS data for opacity, sulfur dioxide, nitrogen
oxides, and carbon monoxide, load level data, and particulate matter
control device temperature data shall be maintained for at least 2 years
after date of recordation and be made available for inspection upon
request.
(j) Records showing the names of persons who have completed review
of the operating manual, including the date
[[Page 162]]
of the initial review and all subsequent annual reviews, shall be
maintained for at least 2 years after date of review and be made
available for inspection upon request.
[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65387, Dec. 19, 1995; 64
FR 7465, Feb. 12, 1999]
Subpart Eb--Standards of Performance for Large Municipal Waste
Combustors for Which Construction is Commenced After September 20, 1994
or for Which Modification or Reconstruction is Commenced After June 19,
1996
Source: 60 FR 65419, Dec. 19, 1995, unless otherwise noted.
Sec. 60.50b Applicability and delegation of authority.
(a) The affected facility to which this subpart applies is each
municipal waste combustor unit with a combustion capacity greater than
250 tons per day of municipal solid waste for which construction is
commenced after September 20, 1994 or for which modification or
reconstruction is commenced after June 19, 1996.
(b) Any waste combustion unit that is capable of combusting more
than 250 tons per day of municipal solid waste and is subject to a
federally enforceable permit limiting the maximum amount of municipal
solid waste that may be combusted in the unit to less than or equal to
11 tons per day is not subject to this subpart if the owner or operator:
(1) Notifies the EPA Administrator of an exemption claim;
(2) Provides a copy of the federally enforceable permit that limits
the firing of municipal solid waste to less than 11 tons per day; and
(3) Keeps records of the amount of municipal solid waste fired on a
daily basis.
(c) An affected facility to which this subpart applies is not
subject to subpart E or Ea of this part.
(d) Physical or operational changes made to an existing municipal
waste combustor unit primarily for the purpose of complying with
emission guidelines under subpart Cb are not considered a modification
or reconstruction and do not result in an existing municipal waste
combustor unit becoming subject to this subpart.
(e) A qualifying small power production facility, as defined in
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that
burns homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy is
not subject to this subpart if the owner or operator of the facility
notifies the EPA Administrator of this exemption and provides data
documenting that the facility qualifies for this exemption.
(f) A qualifying cogeneration facility, as defined in section
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns
homogeneous waste (such as automotive tires or used oil, but not
including refuse-derived fuel) for the production of electric energy and
steam or forms of useful energy (such as heat) that are used for
industrial, commercial, heating, or cooling purposes, is not subject to
this subpart if the owner or operator of the facility notifies the EPA
Administrator of this exemption and provides data documenting that the
facility qualifies for this exemption.
(g) Any unit combusting a single-item waste stream of tires is not
subject to this subpart if the owner or operator of the unit:
(1) Notifies the EPA Administrator of an exemption claim; and
(2) [Reserved]
(3) Provides data documenting that the unit qualifies for this
exemption.
(h) Any unit required to have a permit under section 3005 of the
Solid Waste Disposal Act is not subject to this subpart.
(i) Any materials recovery facility (including primary or secondary
smelters) that combusts waste for the primary purpose of recovering
metals is not subject to this subpart.
(j) Any cofired combustor, as defined under Sec. 60.51b, that meets
the capacity specifications in paragraph (a) of this section is not
subject to this subpart if the owner or operator of the cofired
combustor:
[[Page 163]]
(1) Notifies the EPA Administrator of an exemption claim;
(2) Provides a copy of the federally enforceable permit (specified
in the definition of cofired combustor in this section); and
(3) Keeps a record on a calendar quarter basis of the weight of
municipal solid waste combusted at the cofired combustor and the weight
of all other fuels combusted at the cofired combustor.
(k) Air curtain incinerators, as defined under Sec. 60.51b, located
at a plant that meet the capacity specifications in paragraph (a) of
this section and that combust a fuel stream composed of 100 percent yard
waste are exempt from all provisions of this subpart except the opacity
limit under Sec. 60.56b, the testing procedures under Sec. 60.58b(l),
and the reporting and recordkeeping provisions under Sec. 60.59b (e) and
(i).
(l) Air curtain incinerators located at plants that meet the
capacity specifications in paragraph (a) of this section combusting
municipal solid waste other than yard waste are subject to all
provisions of this subpart.
(m) Pyrolysis/combustion units that are an integrated part of a
plastics/rubber recycling unit (as defined in Sec. 60.51b) are not
subject to this subpart if the owner or operator of the plastics/rubber
recycling unit keeps records of the weight of plastics, rubber, and/or
rubber tires processed on a calendar quarter basis; the weight of
chemical plant feedstocks and petroleum refinery feedstocks produced and
marketed on a calendar quarter basis; and the name and address of the
purchaser of the feedstocks. The combustion of gasoline, diesel fuel,
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke,
liquified petroleum gas, propane, or butane produced by chemical plants
or petroleum refineries that use feedstocks produced by plastics/rubber
recycling units are not subject to this subpart.
(n) The following authorities shall be retained by the Administrator
and not transferred to a State: None.
(o) This subpart shall become effective June 19, 1996.
(p) Cement kilns firing municipal solid waste are not subject to
this subpart.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25,
1997]
Sec. 60.51b Definitions.
Air curtain incinerator means an incinerator that operates by
forcefully projecting a curtain of air across an open chamber or pit in
which burning occurs. Incinerators of this type can be constructed above
or below ground and with or without refractory walls and floor.
Batch municipal waste combustor means a municipal waste combustor
unit designed so that it cannot combust municipal solid waste
continuously 24 hours per day because the design does not allow waste to
be fed to the unit or ash to be removed while combustion is occurring.
Bubbling fluidized bed combustor means a fluidized bed combustor in
which the majority of the bed material remains in a fluidized state in
the primary combustion zone.
Calendar quarter means a consecutive 3-month period (nonoverlapping)
beginning on January 1, April 1, July 1, and October 1.
Calendar year means the period including 365 days starting January 1
and ending on December 31.
Chief facility operator means the person in direct charge and
control of the operation of a municipal waste combustor and who is
responsible for daily onsite supervision, technical direction,
management, and overall performance of the facility.
Circulating fluidized bed combustor means a fluidized bed combustor
in which the majority of the fluidized bed material is carried out of
the primary combustion zone and is transported back to the primary zone
through a recirculation loop.
Clean wood means untreated wood or untreated wood products including
clean untreated lumber, tree stumps (whole or chipped), and tree limbs
(whole or chipped). Clean wood does not include yard waste, which is
defined elsewhere in this section, or construction, renovation, and
demolition wastes (including but not limited to railroad ties and
telephone poles),
[[Page 164]]
which are exempt from the definition of municipal solid waste in this
section.
Cofired combustor means a unit combusting municipal solid waste with
nonmunicipal solid waste fuel (e.g., coal, industrial process waste) and
subject to a federally enforceable permit limiting the unit to
combusting a fuel feed stream, 30 percent or less of the weight of which
is comprised, in aggregate, of municipal solid waste as measured on a
calendar quarter basis.
Continuous emission monitoring system means a monitoring system for
continuously measuring the emissions of a pollutant from an affected
facility.
Dioxin/furan means tetra- through octa- chlorinated dibenzo-p-
dioxins and dibenzofurans.
Federally enforceable means all limitations and conditions that are
enforceable by the Administrator including the requirements of 40 CFR
parts 60, 61, and 63, requirements within any applicable State
implementation plan, and any permit requirements established under 40
CFR 52.21 or under 40 CFR 51.18 and 40 CFR 51.24.
First calendar half means the period starting on January 1 and
ending on June 30 in any year.
Four-hour block average or 4-hour block average means the average of
all hourly emission concentrations when the affected facility is
operating and combusting municipal solid waste measured over 4-hour
periods of time from 12:00 midnight to 4 a.m., 4 a.m. to 8 a.m., 8 a.m.
to 12:00 noon, 12:00 noon to 4 p.m., 4 p.m. to 8 p.m., and 8 p.m. to
12:00 midnight.
Mass burn refractory municipal waste combustor means a field-erected
combustor that combusts municipal solid waste in a refractory wall
furnace. Unless otherwise specified, this includes combustors with a
cylindrical rotary refractory wall furnace.
Mass burn rotary waterwall municipal waste combustor means a field-
erected combustor that combusts municipal solid waste in a cylindrical
rotary waterwall furnace.
Mass burn waterwall municipal waste combustor means a field-erected
combustor that combusts municipal solid waste in a waterwall furnace.
Materials separation plan means a plan that identifies both a goal
and an approach to separate certain components of municipal solid waste
for a given service area in order to make the separated materials
available for recycling. A materials separation plan may include
elements such as dropoff facilities, buy-back or deposit-return
incentives, curbside pickup programs, or centralized mechanical
separation systems. A materials separation plan may include different
goals or approaches for different subareas in the service area, and may
include no materials separation activities for certain subareas or, if
warranted, an entire service area.
Maximum demonstrated municipal waste combustor unit load means the
highest 4-hour arithmetic average municipal waste combustor unit load
achieved during four consecutive hours during the most recent dioxin/
furan performance test demonstrating compliance with the applicable
limit for municipal waste combustor organics specified under
Sec. 60.52b(c).
Maximum demonstrated particulate matter control device temperature
means the highest 4-hour arithmetic average flue gas temperature
measured at the particulate matter control device inlet during four
consecutive hours during the most recent dioxin/furan performance test
demonstrating compliance with the applicable limit for municipal waste
combustor organics specified under Sec. 60.52b(c).
Modification or modified municipal waste combustor unit means a
municipal waste combustor unit to which changes have been made after
June 19, 1996 if the cumulative cost of the changes, over the life of
the unit, exceed 50 percent of the original cost of construction and
installation of the unit (not including the cost of any land purchased
in connection with such construction or installation) updated to current
costs; or any physical change in the municipal waste combustor unit or
change in the method of operation of the municipal waste combustor unit
increases the amount of any air pollutant emitted by the unit for which
standards have been established under section 129 or section 111.
Increases in
[[Page 165]]
the amount of any air pollutant emitted by the municipal waste combustor
unit are determined at 100-percent physical load capability and
downstream of all air pollution control devices, with no consideration
given for load restrictions based on permits or other nonphysical
operational restrictions.
Modular excess-air municipal waste combustor means a combustor that
combusts municipal solid waste and that is not field-erected and has
multiple combustion chambers, all of which are designed to operate at
conditions with combustion air amounts in excess of theoretical air
requirements.
Modular starved-air municipal waste combustor means a combustor that
combusts municipal solid waste and that is not field-erected and has
multiple combustion chambers in which the primary combustion chamber is
designed to operate at substoichiometric conditions.
Municipal solid waste or municipal-type solid waste or MSW means
household, commercial/retail, and/or institutional waste. Household
waste includes material discarded by single and multiple residential
dwellings, hotels, motels, and other similar permanent or temporary
housing establishments or facilities. Commercial/retail waste includes
material discarded by stores, offices, restaurants, warehouses,
nonmanufacturing activities at industrial facilities, and other similar
establishments or facilities. Institutional waste includes material
discarded by schools, nonmedical waste discarded by hospitals, material
discarded by nonmanufacturing activities at prisons and government
facilities, and material discarded by other similar establishments or
facilities. Household, commercial/retail, and institutional waste does
not include used oil; sewage sludge; wood pallets; construction,
renovation, and demolition wastes (which includes but is not limited to
railroad ties and telephone poles); clean wood; industrial process or
manufacturing wastes; medical waste; or motor vehicles (including motor
vehicle parts or vehicle fluff). Household, commercial/retail, and
institutional wastes include:
(1) Yard waste;
(2) Refuse-derived fuel; and
(3) Motor vehicle maintenance materials limited to vehicle batteries
and tires except as specified in Sec. 60.50b(g).
Municipal waste combustor, MWC, or municipal waste combustor unit:
(1) Means any setting or equipment that combusts solid, liquid, or
gasified municipal solid waste including, but not limited to, field-
erected incinerators (with or without heat recovery), modular
incinerators (starved-air or excess-air), boilers (i.e., steam
generating units), furnaces (whether suspension-fired, grate-fired,
mass-fired, air curtain incinerators, or fluidized bed-fired), and
pyrolysis/combustion units. Municipal waste combustors do not include
pyrolysis/combustion units located at a plastics/rubber recycling unit
(as specified in Sec. 60.50b(m)). Municipal waste combustors do not
include cement kilns firing municipal solid waste (as specified in
Sec. 60.50b(p)). Municipal waste combustors do not include internal
combustion engines, gas turbines, or other combustion devices that
combust landfill gases collected by landfill gas collection systems.
(2) The boundaries of a municipal solid waste combustor are defined
as follows. The municipal waste combustor unit includes, but is not
limited to, the municipal solid waste fuel feed system, grate system,
flue gas system, bottom ash system, and the combustor water system. The
municipal waste combustor boundary starts at the municipal solid waste
pit or hopper and extends through:
(i) The combustor flue gas system, which ends immediately following
the heat recovery equipment or, if there is no heat recovery equipment,
immediately following the combustion chamber,
(ii) The combustor bottom ash system, which ends at the truck
loading station or similar ash handling equipment that transfer the ash
to final disposal, including all ash handling systems that are connected
to the bottom ash handling system; and
(iii) The combustor water system, which starts at the feed water
pump and ends at the piping exiting the steam drum or superheater.
[[Page 166]]
(3) The municipal waste combustor unit does not include air
pollution control equipment, the stack, water treatment equipment, or
the turbine-generator set.
Municipal waste combustor acid gases means all acid gases emitted in
the exhaust gases from municipal waste combustor units including, but
not limited to, sulfur dioxide and hydrogen chloride gases.
Municipal waste combustor metals means metals and metal compounds
emitted in the exhaust gases from municipal waste combustor units.
Municipal waste combustor organics means organic compounds emitted
in the exhaust gases from municipal waste combustor units and includes
tetra-through octa- chlorinated dibenzo-p-dioxins and dibenzofurans.
Municipal waste combustor plant means one or more affected
facilities (as defined in Sec. 60.50b) at the same location.
Municipal waste combustor unit capacity means the maximum charging
rate of a municipal waste combustor unit expressed in tons per day of
municipal solid waste combusted, calculated according to the procedures
under Sec. 60.58b(j). Section 60.58b(j) includes procedures for
determining municipal waste combustor unit capacity for continuous and
batch feed municipal waste combustors.
Municipal waste combustor unit load means the steam load of the
municipal waste combustor unit measured as specified in
Sec. 60.58b(i)(6).
Particulate matter means total particulate matter emitted from
municipal waste combustor units as measured by EPA Reference Method 5
(see Sec. 60.58b(c)).
Plastics/rubber recycling unit means an integrated processing unit
where plastics, rubber, and/or rubber tires are the only feed materials
(incidental contaminants may be included in the feed materials) and they
are processed into a chemical plant feedstock or petroleum refinery
feedstock, where the feedstock is marketed to and used by a chemical
plant or petroleum refinery as input feedstock. The combined weight of
the chemical plant feedstock and petroleum refinery feedstock produced
by the plastics/rubber recycling unit on a calendar quarter basis shall
be more than 70 percent of the combined weight of the plastics, rubber,
and rubber tires processed by the plastics/rubber recycling unit on a
calendar quarter basis. The plastics, rubber, and/or rubber tire feed
materials to the plastics/rubber recycling unit may originate from the
separation or diversion of plastics, rubber, or rubber tires from MSW or
industrial solid waste, and may include manufacturing scraps, trimmings,
and off-specification plastics, rubber, and rubber tire discards. The
plastics, rubber, and rubber tire feed materials to the plastics/rubber
recycling unit may contain incidental contaminants (e.g., paper labels
on plastic bottles, metal rings on plastic bottle caps, etc.).
Potential hydrogen chloride emission concentration means the
hydrogen chloride emission concentration that would occur from
combustion of municipal solid waste in the absence of any emission
controls for municipal waste combustor acid gases.
Potential mercury emission concentration means the mercury emission
concentration that would occur from combustion of municipal solid waste
in the absence of any mercury emissions control.
Potential sulfur dioxide emissions means the sulfur dioxide emission
concentration that would occur from combustion of municipal solid waste
in the absence of any emission controls for municipal waste combustor
acid gases.
Pulverized coal/refuse-derived fuel mixed fuel-fired combustor means
a combustor that fires coal and refuse-derived fuel simultaneously, in
which pulverized coal is introduced into an air stream that carries the
coal to the combustion chamber of the unit where it is fired in
suspension. This includes both conventional pulverized coal and
micropulverized coal.
Pyrolysis/combustion unit means a unit that produces gases, liquids,
or solids through the heating of municipal solid waste, and the gases,
liquids, or solids produced are combusted and emissions vented to the
atmosphere.
Reconstruction means rebuilding a municipal waste combustor unit for
which the reconstruction commenced after June 19, 1996, and the
cumulative
[[Page 167]]
costs of the construction over the life of the unit exceed 50 percent of
the original cost of construction and installation of the unit (not
including any cost of land purchased in connection with such
construction or installation) updated to current costs (current
dollars).
Refractory unit or refractory wall furnace means a combustion unit
having no energy recovery (e.g., via a waterwall) in the furnace (i.e.,
radiant heat transfer section) of the combustor.
Refuse-derived fuel means a type of municipal solid waste produced
by processing municipal solid waste through shredding and size
classification. This includes all classes of refuse-derived fuel
including low-density fluff refuse-derived fuel through densified
refuse-derived fuel and pelletized refuse-derived fuel.
Refuse-derived fuel stoker means a steam generating unit that
combusts refuse-derived fuel in a semisuspension firing mode using air-
fed distributors.
Same location means the same or contiguous property that is under
common ownership or control including properties that are separated only
by a street, road, highway, or other public right-of-way. Common
ownership or control includes properties that are owned, leased, or
operated by the same entity, parent entity, subsidiary, subdivision, or
any combination thereof including any municipality or other governmental
unit, or any quasi-governmental authority (e.g., a public utility
district or regional waste disposal authority).
Second calendar half means the period starting July 1 and ending on
December 31 in any year.
Shift supervisor means the person who is in direct charge and
control of the operation of a municipal waste combustor and who is
responsible for onsite supervision, technical direction, management, and
overall performance of the facility during an assigned shift.
Spreader stoker coal/refuse-derived fuel mixed fuel-fired combustor
means a combustor that fires coal and refuse-derived fuel
simultaneously, in which coal is introduced to the combustion zone by a
mechanism that throws the fuel onto a grate from above. Combustion takes
place both in suspension and on the grate.
Standard conditions means a temperature of 20 deg.C and a pressure
of 101.3 kilopascals.
Total mass dioxin/furan or total mass means the total mass of tetra-
through octa- chlorinated dibenzo-p-dioxins and dibenzofurans, as
determined using EPA Reference Method 23 and the procedures specified
under Sec. 60.58b(g).
Twenty-four hour daily average or 24-hour daily average means either
the arithmetic mean or geometric mean (as specified) of all hourly
emission concentrations when the affected facility is operating and
combusting municipal solid waste measured over a 24-hour period between
12:00 midnight and the following midnight.
Untreated lumber means wood or wood products that have been cut or
shaped and include wet, air-dried, and kiln-dried wood products.
Untreated lumber does not include wood products that have been painted,
pigment-stained, or ``pressure-treated.'' Pressure-treating compounds
include, but are not limited to, chromate copper arsenate,
pentachlorophenol, and creosote.
Waterwall furnace means a combustion unit having energy (heat)
recovery in the furnace (i.e., radiant heat transfer section) of the
combustor.
Yard waste means grass, grass clippings, bushes, shrubs, and
clippings from bushes and shrubs that are generated by residential,
commercial/retail, institutional, and/or industrial sources as part of
maintenance activities associated with yards or other private or public
lands. Yard waste does not include construction, renovation, and
demolition wastes, which are exempt from the definition of municipal
solid waste in this section. Yard waste does not include clean wood,
which is exempt from the definition of municipal solid waste in this
section.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45126, Aug. 25,
1997]
Sec. 60.52b Standards for municipal waste combustor metals, acid gases, organics, and nitrogen oxides.
(a) The limits for municipal waste combustor metals are specified in
paragraphs (a)(1) through (a)(5) of this section.
[[Page 168]]
(1) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that contain particulate matter in excess of 24 milligrams per dry
standard cubic meter, corrected to 7 percent oxygen.
(2) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that exhibit greater than 10 percent opacity (6-minute average).
(3) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that contain cadmium in excess of 0.020 milligrams per dry standard
cubic meter, corrected to 7 percent oxygen.
(4) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from the affected facility any gases
that contain lead in excess of 0.20 milligrams per dry standard cubic
meter, corrected to 7 percent oxygen.
(5) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from the affected facility any gases
that contain mercury in excess of 0.080 milligrams per dry standard
cubic meter or 15 percent of the potential mercury emission
concentration (85-percent reduction by weight), corrected to 7 percent
oxygen, whichever is less stringent.
(b) The limits for municipal waste combustor acid gases are
specified in paragraphs (b)(1) and (b)(2) of this section.
(1) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that contain sulfur dioxide in excess of 30 parts per million by volume
or 20 percent of the potential sulfur dioxide emission concentration
(80-percent reduction by weight or volume), corrected to 7 percent
oxygen (dry basis), whichever is less stringent. The averaging time is
specified under Sec. 60.58b(e).
(2) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that contain hydrogen chloride in excess of 25 parts per million by
volume or 5 percent of the potential hydrogen chloride emission
concentration (95-percent reduction by weight or volume), corrected to 7
percent oxygen (dry basis), whichever is less stringent.
(c) The limits for municipal waste combustor organics are specified
in paragraphs (c)(1) and (c)(2) of this section.
(1) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility for which
construction, modification or reconstruction commences on or before
November 20, 1997 shall cause to be discharged into the atmosphere from
that affected facility any gases that contain dioxin/furan emissions
that exceed 30 nanograms per dry standard cubic meter (total mass),
corrected to 7 percent oxygen, for the first 3 years following the date
of initial startup. After the first 3 years following the date of
initial startup, no owner or operator shall cause to be discharged into
the atmosphere from that affected facility any gases that contain
dioxin/furan total mass emissions that exceed 13 nanograms per dry
standard
[[Page 169]]
cubic meter (total mass), corrected to 7 percent oxygen.
(2) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility for which
construction, modification, or reconstruction commences after November
20, 1997 shall cause to be discharged into the atmosphere from that
affected facility any gases that contain dioxin/furan total mass
emissions that exceed 13 nanograms per dry standard cubic meter (total
mass), corrected to 7 percent oxygen.
(d) The limits for nitrogen oxides are specified in paragraphs
(d)(1) and (d)(2) of this section.
(1) During the first year of operation after the date on which the
initial performance test is completed or is required to be completed
under Sec. 60.8 of subpart A of this part, no owner or operator of an
affected facility shall cause to be discharged into the atmosphere from
that affected facility any gases that contain nitrogen oxides in excess
of 180 parts per million by volume, corrected to 7 percent oxygen (dry
basis). The averaging time is specified under Sec. 60.58b(h).
(2) After the first year of operation following the date on which
the initial performance test is completed or is required to be completed
under Sec. 60.8 of subpart A of this part, no owner or operator of an
affected facility shall cause to be discharged into the atmosphere from
that affected facility any gases that contain nitrogen oxides in excess
of 150 parts per million by volume, corrected to 7 percent oxygen (dry
basis). The averaging time is specified under Sec. 60.58b(h).
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45126, Aug. 25,
1997]
Sec. 60.53b Standards for municipal waste combustor operating practices.
(a) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from that affected facility any gases
that contain carbon monoxide in excess of the emission limits specified
in table 1 of this subpart.
Table 1.--Municipal Waste Combustor Operating Standards
------------------------------------------------------------------------
Carbon monoxide
emission limit
Municipal waste combustor technology (parts per Averaging time
million by (hours) \b\
volume) \a\
------------------------------------------------------------------------
Mass burn waterwall................. 100 4
Mass burn refractory................ 100 4
Mass burn rotary waterwall.......... 100 24
Modular starved air................. 50 4
Modular excess air.................. 50 4
Refuse-derived fuel stoker.......... 150 24
Bubbling fluidized bed combustor.... 100 4
Circulating fluidized bed combustor. 100 4
Pulverized coal/refuse-derived fuel 150 4
mixed fuel-fired combustor.........
Spreader stoker coal/refuse-derived 150 24
fuel mixed fuel-fired combustor....
------------------------------------------------------------------------
\a \ Measured at the combustor outlet in conjunction with a measurement
of oxygen concentration, corrected to 7 percent oxygen (dry basis).
The averaging times are specified in greater detail in Sec.
60.58b(i).
\b \ Averaging times are 4-hour or 24-hour block averages.
(b) No owner or operator of an affected facility shall cause such
facility to operate at a load level greater than 110 percent of the
maximum demonstrated municipal waste combustor unit load as defined in
Sec. 60.51b, except as specified in paragraphs (b)(1) and (b)(2) of this
section. The averaging time is specified under Sec. 60.58b(i).
(1) During the annual dioxin/furan performance test and the 2 weeks
preceding the annual dioxin/furan performance test, no municipal waste
combustor unit load limit is applicable.
[[Page 170]]
(2) The municipal waste combustor unit load limit may be waived in
accordance with permission granted by the Administrator or delegated
State regulatory authority for the purpose of evaluating system
performance, testing new technology or control technologies, diagnostic
testing, or related activities for the purpose of improving facility
performance or advancing the state-of-the-art for controlling facility
emissions.
(c) No owner or operator of an affected facility shall cause such
facility to operate at a temperature, measured at the particulate matter
control device inlet, exceeding 17 deg.C above the maximum demonstrated
particulate matter control device temperature as defined in Sec. 60.51b,
except as specified in paragraphs (c)(1) and (c)(2) of this section. The
averaging time is specified under Sec. 60.58b(i). The requirements
specified in this paragraph apply to each particulate matter control
device utilized at the affected facility.
(1) During the annual dioxin/furan performance test and the 2 weeks
preceding the annual dioxin/furan performance test, no particulate
matter control device temperature limitations are applicable.
(2) The particulate matter control device temperature limits may be
waived in accordance with permission granted by the Administrator or
delegated State regulatory authority for the purpose of evaluating
system performance, testing new technology or control technologies,
diagnostic testing, or related activities for the purpose of improving
facility performance or advancing the state-of-the-art for controlling
facility emissions.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]
Sec. 60.54b Standards for municipal waste combustor operator training and certification.
(a) No later than the date 6 months after the date of startup of an
affected facility or on December 19, 1996, whichever is later, each
chief facility operator and shift supervisor shall obtain and maintain a
current provisional operator certification from either the American
Society of Mechanical Engineers [QRO-1-1994 (incorporated by reference--
see Sec. 60.17 of subpart A of this part)] or a State certification
program.
(b) Not later than the date 6 months after the date of startup of an
affected facility or on December 19, 1996, whichever is later, each
chief facility operator and shift supervisor shall have completed full
certification or shall have scheduled a full certification exam with
either the American Society of Mechanical Engineers [QRO-1-1994
(incorporated by reference--see Sec. 60.17 of subpart A of this part)]
or a State certification program.
(c) No owner or operator of an affected facility shall allow the
facility to be operated at any time unless one of the following persons
is on duty and at the affected facility: A fully certified chief
facility operator, a provisionally certified chief facility operator who
is scheduled to take the full certification exam according to the
schedule specified in paragraph (b) of this section, a fully certified
shift supervisor, or a provisionally certified shift supervisor who is
scheduled to take the full certification exam according to the schedule
specified in paragraph (b) of this section.
(1) The requirement specified in paragraph (c) of this section shall
take effect 6 months after the date of startup of the affected facility
or on December 19, 1996, whichever is later.
(2) If one of the persons listed in paragraph (c) of this section
must leave the affected facility during their operating shift, a
provisionally certified control room operator who is onsite at the
affected facility may fulfill the requirement in paragraph (c) of this
section.
(d) All chief facility operators, shift supervisors, and control
room operators at affected facilities must complete the EPA or State
municipal waste combustor operator training course no later than the
date 6 months after the date of startup of the affected facility or by
December 19, 1996, whichever is later.
(e) The owner or operator of an affected facility shall develop and
update on a yearly basis a site-specific operating manual that shall, at
a minimum, address the elements of municipal waste combustor unit
operation
[[Page 171]]
specified in paragraphs (e)(1) through (e)(11) of this section.
(1) A summary of the applicable standards under this subpart;
(2) A description of basic combustion theory applicable to a
municipal waste combustor unit;
(3) Procedures for receiving, handling, and feeding municipal solid
waste;
(4) Municipal waste combustor unit startup, shutdown, and
malfunction procedures;
(5) Procedures for maintaining proper combustion air supply levels;
(6) Procedures for operating the municipal waste combustor unit
within the standards established under this subpart;
(7) Procedures for responding to periodic upset or off-specification
conditions;
(8) Procedures for minimizing particulate matter carryover;
(9) Procedures for handling ash;
(10) Procedures for monitoring municipal waste combustor unit
emissions; and
(11) Reporting and recordkeeping procedures.
(f) The owner or operator of an affected facility shall establish a
training program to review the operating manual according to the
schedule specified in paragraphs (f)(1) and (f)(2) of this section with
each person who has responsibilities affecting the operation of an
affected facility including, but not limited to, chief facility
operators, shift supervisors, control room operators, ash handlers,
maintenance personnel, and crane/load handlers.
(1) Each person specified in paragraph (f) of this section shall
undergo initial training no later than the date specified in paragraph
(f)(1)(i), (f)(1)(ii), or (f)(1)(iii) of this section whichever is
later.
(i) The date 6 months after the date of startup of the affected
facility;
(ii) The date prior to the day the person assumes responsibilities
affecting municipal waste combustor unit operation; or
(iii) December 19, 1996.
(2) Annually, following the initial review required by paragraph
(f)(1) of this section.
(g) The operating manual required by paragraph (e) of this section
shall be kept in a readily accessible location for all persons required
to undergo training under paragraph (f) of this section. The operating
manual and records of training shall be available for inspection by the
EPA or its delegated enforcement agency upon request.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]
Sec. 60.55b Standards for municipal waste combustor fugitive ash emissions.
(a) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, no owner or operator of an affected facility shall cause to
be discharged to the atmosphere visible emissions of combustion ash from
an ash conveying system (including conveyor transfer points) in excess
of 5 percent of the observation period (i.e., 9 minutes per 3-hour
period), as determined by EPA Reference Method 22 observations as
specified in Sec. 60.58b(k), except as provided in paragraphs (b) and
(c) of this section.
(b) The emission limit specified in paragraph (a) of this section
does not cover visible emissions discharged inside buildings or
enclosures of ash conveying systems; however, the emission limit
specified in paragraph (a) of this section does cover visible emissions
discharged to the atmosphere from buildings or enclosures of ash
conveying systems.
(c) The provisions specified in paragraph (a) of this section do not
apply during maintenance and repair of ash conveying systems.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]
Sec. 60.56b Standards for air curtain incinerators.
On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, the owner or operator of an air curtain incinerator with the
capacity to combust greater than 250 tons per day of municipal solid
waste and that combusts a
[[Page 172]]
fuel feed stream composed of 100 percent yard waste and no other
municipal solid waste materials shall at no time cause to be discharged
into the atmosphere from that incinerator any gases that exhibit greater
than 10-percent opacity (6-minute average), except that an opacity level
of up to 35 percent (6-minute average) is permitted during startup
periods during the first 30 minutes of operation of the unit.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]
Sec. 60.57b Siting requirements.
(a) The owner or operator of an affected facility for which the
initial application for a construction permit under 40 CFR part 51,
subpart I, or part 52, as applicable, is submitted after December 19,
1995, shall prepare a materials separation plan, as defined in
Sec. 60.51b, for the affected facility and its service area, and shall
comply with the requirements specified in paragraphs (a)(1) through
(a)(10) of this section. The initial application is defined as
representing a good faith submittal for complying with the requirements
under 40 CFR part 51, subpart I, or part 52, as applicable, as
determined by the Administrator.
(1) The owner or operator shall prepare a preliminary draft
materials separation plan and shall make the plan available to the
public as specified in paragraphs (a)(1)(i) and (a)(1)(ii) of this
section.
(i) The owner or operator shall distribute the preliminary draft
materials separation plan to the principal public libraries in the area
where the affected facility is to be constructed.
(ii) The owner or operator shall publish a notification of a public
meeting in the principal newspaper(s) serving the area where the
affected facility is to be constructed and where the waste treated by
the affected facility will primarily be collected. As a minimum, the
notification shall include the information specified in paragraphs
(a)(1)(ii)(A) through (a)(1)(ii)(D) of this section.
(A) The date, time, and location of the public meeting.
(B) The location of the public libraries where the preliminary draft
materials separation plan may be found, including normal business hours
of the libraries.
(C) An agenda of the issues to be discussed at the public meeting.
(D) The dates that the public comment period on the preliminary
draft materials separation plan begins and ends.
(2) The owner or operator shall conduct a public meeting, accept
comments on the preliminary draft materials separation plan, and comply
with the requirements specified in paragraphs (a)(2)(i) through
(a)(2)(iv) of this section.
(i) The public meeting shall be conducted in the county where the
affected facility is to be located.
(ii) The public meeting shall be scheduled to occur 30 days or more
after making the preliminary draft materials separation plan available
to the public as specified under paragraph (a)(1) of this section.
(iii) Suggested issues to be addressed at the public meeting are
listed in paragraphs (a)(2)(iii)(A) through (a)(2)(iii)(H) of this
section.
(A) The expected size of the service area for the affected facility.
(B) The amount of waste generation anticipated for the service area.
(C) The types and estimated amounts of materials proposed for
separation.
(D) The methods proposed for materials separation.
(E) The amount of residual waste to be disposed.
(F) Alternate disposal methods for handling the residual waste.
(G) Identification of the location(s) where responses to public
comment on the preliminary draft materials separation plan will be
available for inspection, as specified in paragraphs (a)(3) and (a)(4)
of this section.
(H) Identification of the locations where the final draft materials
separation plan will be available for inspection, as specified in
paragraph (a)(7).
(iv) Nothing in this section shall preclude an owner or operator
from combining this public meeting with any other public meeting
required as part of any other Federal, State, or local permit review
process except the public meeting required under paragraph (b)(4) of
this section.
[[Page 173]]
(3) Following the public meeting required by paragraph (a)(2) of
this section, the owner or operator shall prepare responses to the
comments received at the public meeting.
(4) The owner or operator shall make the document summarizing
responses to public comments available to the public (including
distribution to the principal public libraries used to announce the
meeting) in the service area where the affected facility is to be
located.
(5) The owner or operator shall prepare a final draft materials
separation plan for the affected facility considering the public
comments received at the public meeting.
(6) As required under Sec. 60.59b(a), the owner or operator shall
submit to the Administrator a copy of the notification of the public
meeting, a transcript of the public meeting, the document summarizing
responses to public comments, and copies of both the preliminary and
final draft materials separation plans on or before the time the
facility's application for a construction permit is submitted under 40
CFR part 51, subpart I, or part 52, as applicable.
(7) As part of the distribution of the siting analysis required
under paragraph (b)(3) of this section, the owner or operator shall make
the final draft materials separation plan required under paragraph
(a)(5) of this section available to the public, as specified in
paragraph (b)(3) of this section.
(8) As part of the public meeting for review of the siting analysis
required under paragraph (b)(4) of this section, the owner or operator
shall address questions concerning the final draft materials separation
plan required by paragraph (a)(5) of this section including discussion
of how the final draft materials separation plan has changed from the
preliminary draft materials separation plan that was discussed at the
first public meeting required by paragraph (a)(2) of this section.
(9) If the owner or operator receives any comments on the final
draft materials separation plan during the public meeting required in
paragraph (b)(4) of this section, the owner or operator shall respond to
those comments in the document prepared in accordance with paragraph
(b)(5) of this section.
(10) The owner or operator shall prepare a final materials
separation plan and shall submit, as required under
Sec. 60.59b(b)(5)(ii), the final materials separation plan as part of
the initial notification of construction.
(b) The owner or operator of an affected facility for which the
initial application for a construction permit under 40 CFR part 51,
subpart I, or part 52, as applicable, is submitted after December 19,
1995 shall prepare a siting analysis in accordance with paragraphs
(b)(1) and (b)(2) of this section and shall comply with the requirements
specified in paragraphs (b)(3) through (b)(7) of this section.
(1) The siting analysis shall be an analysis of the impact of the
affected facility on ambient air quality, visibility, soils, and
vegetation.
(2) The analysis shall consider air pollution control alternatives
that minimize, on a site-specific basis, to the maximum extent
practicable, potential risks to the public health or the environment.
(3) The owner or operator shall make the siting analysis and final
draft materials separation plan required by paragraph (a)(5) of this
section available to the public as specified in paragraphs (b)(3)(i) and
(b)(3)(ii) of this section.
(i) The owner or operator shall distribute the siting analysis and
final draft materials separation plan to the principal public libraries
in the area where the affected facility is to be constructed.
(ii) The owner or operator shall publish a notification of a public
meeting in the principal newspaper(s) serving the area where the
affected facility is to be constructed and where the waste treated by
the affected facility will primarily be collected. As a minimum, the
notification shall include the information specified in paragraphs
(b)(3)(ii)(A) through (b)(3)(ii)(D) of this section.
(A) The date, time, and location of the public meeting.
(B) The location of the public libraries where the siting analyses
and final draft materials separation plan may be found, including normal
business hours.
[[Page 174]]
(C) An agenda of the issues to be discussed at the public meeting.
(D) The dates that the public comment period on the siting analyses
and final draft materials separation plan begins and ends.
(4) The owner or operator shall conduct a public meeting and accept
comments on the siting analysis and the final draft materials separation
plan required under paragraph (a)(5) of this section. The public meeting
shall be conducted in the county where the affected facility is to be
located and shall be scheduled to occur 30 days or more after making the
siting analysis available to the public as specified under paragraph
(b)(3) of this section.
(5) The owner or operator shall prepare responses to the comments on
the siting analysis and the final draft materials separation plan that
are received at the public meeting.
(6) The owner or operator shall make the document summarizing
responses to public comments available to the public (including
distribution to all public libraries) in the service area where the
affected facility is to be located.
(7) As required under Sec. 60.59b(b)(5), the owner or operator shall
submit a copy of the notification of the public meeting, a transcript of
the public meeting, the document summarizing responses to public
comments, and the siting analysis as part of the initial notification of
construction.
(c) The owner or operator of an affected facility for which
construction is commenced after September 20, 1994 shall prepare a
siting analysis in accordance with 40 CFR part 51, Subpart I, or part
52, as applicable, and shall submit the siting analysis as part of the
initial notification of construction. Affected facilities subject to
paragraphs (a) and (b) of this section are not subject to this
paragraph.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]
Sec. 60.58b Compliance and performance testing.
(a) The provisions for startup, shutdown, and malfunction are
provided in paragraphs (a)(1) and (a)(2) of this section.
(1) Except as provided by Sec. 60.56b, the standards under this
subpart apply at all times except during periods of startup, shutdown,
or malfunction. Duration of startup, shutdown, or malfunction periods
are limited to 3 hours per occurrence.
(i) The startup period commences when the affected facility begins
the continuous burning of municipal solid waste and does not include any
warmup period when the affected facility is combusting fossil fuel or
other nonmunicipal solid waste fuel, and no municipal solid waste is
being fed to the combustor.
(ii) Continuous burning is the continuous, semicontinuous, or batch
feeding of municipal solid waste for purposes of waste disposal, energy
production, or providing heat to the combustion system in preparation
for waste disposal or energy production. The use of municipal solid
waste solely to provide thermal protection of the grate or hearth during
the startup period when municipal solid waste is not being fed to the
grate is not considered to be continuous burning.
(2) The opacity limits for air curtain incinerators specified in
Sec. 60.56b apply at all times as specified under Sec. 60.56b except
during periods of malfunction. Duration of malfunction periods are
limited to 3 hours per occurrence.
(b) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous emission monitoring system
and record the output of the system for measuring the oxygen or carbon
dioxide content of the flue gas at each location where carbon monoxide,
sulfur dioxide, or nitrogen oxides emissions are monitored and shall
comply with the test procedures and test methods specified in paragraphs
(b)(1) through (b)(7) of this section.
(1) The span value of the oxygen (or 20 percent carbon dioxide)
monitor shall be 25 percent oxygen (or 20 percent carbon dioxide).
(2) The monitor shall be installed, evaluated, and operated in
accordance with Sec. 60.13 of subpart A of this part.
(3) The initial performance evaluation shall be completed no later
than
[[Page 175]]
180 days after the date of initial startup of the affected facility, as
specified under Sec. 60.8 of subpart A of this part.
(4) The monitor shall conform to Performance Specification 3 in
appendix B of this part except for section 2.3 (relative accuracy
requirement).
(5) The quality assurance procedures of appendix F of this part
except for section 5.1.1 (relative accuracy test audit) shall apply to
the monitor.
(6) If carbon dioxide is selected for use in diluent corrections,
the relationship between oxygen and carbon dioxide levels shall be
established during the initial performance test according to the
procedures and methods specified in paragraphs (b)(6)(i) through
(b)(6)(iv) of this section. This relationship may be reestablished
during performance compliance tests.
(i) The fuel factor equation in Method 3B shall be used to determine
the relationship between oxygen and carbon dioxide at a sampling
location. Method 3, 3A, or 3B, as applicable, shall be used to determine
the oxygen concentration at the same location as the carbon dioxide
monitor.
(ii) Samples shall be taken for at least 30 minutes in each hour.
(iii) Each sample shall represent a 1-hour average.
(iv) A minimum of three runs shall be performed.
(7) The relationship between carbon dioxide and oxygen
concentrations that is established in accordance with paragraph (b)(6)
of this section shall be submitted to the EPA Administrator as part of
the initial performance test report and, if applicable, as part of the
annual test report if the relationship is reestablished during the
annual performance test.
(c) The procedures and test methods specified in paragraphs (c)(1)
through (c)(11) of this section shall be used to determine compliance
with the emission limits for particulate matter and opacity under
Sec. 60.52b(a)(1) and (a)(2).
(1) The EPA Reference Method 1 shall be used to select sampling site
and number of traverse points.
(2) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be
used for gas analysis.
(3) The EPA Reference Method 5 shall be used for determining
compliance with the particulate matter emission limit. The minimum
sample volume shall be 1.7 cubic meters. The probe and filter holder
heating systems in the sample train shall be set to provide a gas
temperature no greater than 160#14 deg.C. An oxygen or
carbon dioxide measurement shall be obtained simultaneously with each
Method 5 run.
(4) The owner or operator of an affected facility may request that
compliance with the particulate matter emission limit be determined
using carbon dioxide measurements corrected to an equivalent of 7
percent oxygen. The relationship between oxygen and carbon dioxide
levels for the affected facility shall be established as specified in
paragraph (b)(6) of this section.
(5) As specified under Sec. 60.8 of subpart A of this part, all
performance tests shall consist of three test runs. The average of the
particulate matter emission concentrations from the three test runs is
used to determine compliance.
(6) In accordance with paragraphs (c)(7) and (c)(11) of this
section, EPA Reference Method 9 shall be used for determining compliance
with the opacity limit except as provided under Sec. 60.11(e) of subpart
A of this part.
(7) The owner or operator of an affected facility shall conduct an
initial performance test for particulate matter emissions and opacity as
required under Sec. 60.8 of subpart A of this part.
(8) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous opacity monitoring system
for measuring opacity and shall follow the methods and procedures
specified in paragraphs (c)(8)(i) through (c)(8)(iv) of this section.
(i) The output of the continuous opacity monitoring system shall be
recorded on a 6-minute average basis.
(ii) The continuous opacity monitoring system shall be installed,
evaluated, and operated in accordance with Sec. 60.13 of subpart A of
this part.
(iii) The continuous opacity monitoring system shall conform to
Performance Specification 1 in appendix B of this part.
(iv) The initial performance evaluation shall be completed no later
than 180 days after the date of the initial
[[Page 176]]
startup of the municipal waste combustor unit, as specified under
Sec. 60.8 of subpart A of this part.
(9) Following the date that the initial performance test for
particulate matter is completed or is required to be completed under
Sec. 60.8 of subpart A of this part for an affected facility, the owner
or operator shall conduct a performance test for particulate matter on
an annual basis (no more than 12 calendar months following the previous
performance test).
(10) [Reserved]
(11) Following the date that the initial performance test for
opacity is completed or is required to be completed under Sec. 60.8 of
subpart A of this part for an affected facility, the owner or operator
shall conduct a performance test for opacity on an annual basis (no more
than 12 calendar months following the previous performance test) using
the test method specified in paragraph (c)(6) of this section.
(d) The procedures and test methods specified in paragraphs (d)(1)
and (d)(2) of this section shall be used to determine compliance with
the emission limits for cadmium, lead, and mercury under Sec. 60.52b(a).
(1) The procedures and test methods specified in paragraphs
(d)(1)(i) through (d)(1)(ix) of this section shall be used to determine
compliance with the emission limits for cadmium and lead under
Sec. 60.52b(a) (3) and (4).
(i) The EPA Reference Method 1 shall be used for determining the
location and number of sampling points.
(ii) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be
used for flue gas analysis.
(iii) The EPA Reference Method 29 shall be used for determining
compliance with the cadmium and lead emission limits.
(iv) An oxygen or carbon dioxide measurement shall be obtained
simultaneously with each Method 29 test run for cadmium and lead
required under paragraph (d)(1)(iii) of this section.
(v) The owner or operator of an affected facility may request that
compliance with the cadmium or lead emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(vi) All performance tests shall consist of a minimum of three test
runs conducted under representative full load operating conditions. The
average of the cadmium or lead emission concentrations from three test
runs or more shall be used to determine compliance.
(vii) Following the date of the initial performance test or the date
on which the initial performance test is required to be completed under
Sec. 60.8 of subpart A of this part, the owner or operator of an
affected facility shall conduct a performance test for compliance with
the emission limits for cadmium and lead on an annual basis (no more
than 12 calendar months following the previous performance test).
(viii)-(ix) [Reserved]
(2) The procedures and test methods specified in paragraphs
(d)(2)(i) through (d)(2)(xi) of this section shall be used to determine
compliance with the mercury emission limit under Sec. 60.52b(a)(5).
(i) The EPA Reference Method 1 shall be used for determining the
location and number of sampling points.
(ii) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be
used for flue gas analysis.
(iii) The EPA Reference Method 29 shall be used to determine the
mercury emission concentration. The minimum sample volume when using
Method 29 for mercury shall be 1.7 cubic meters.
(iv) An oxygen (or carbon dioxide) measurement shall be obtained
simultaneously with each Method 29 test run for mercury required under
paragraph (d)(2)(iii) of this section.
(v) The percent reduction in the potential mercury emissions (%PHg)
is computed using equation 1:
[GRAPHIC] [TIFF OMITTED] TR19DE95.001
where:
%PHg = percent reduction of the potential mercury emissions
achieved.
Ei = potential mercury emission concentration measured at the
control device inlet, corrected to 7 percent oxygen (dry
basis).
[[Page 177]]
Eo = controlled mercury emission concentration measured at
the mercury control device outlet, corrected to 7 percent
oxygen (dry basis).
(vi) All performance tests shall consist of a minimum of three test
runs conducted under representative full load operating conditions. The
average of the mercury emission concentrations or percent reductions
from three test runs or more is used to determine compliance.
(vii) The owner or operator of an affected facility may request that
compliance with the mercury emission limit be determined using carbon
dioxide measurements corrected to an equivalent of 7 percent oxygen. The
relationship between oxygen and carbon dioxide levels for the affected
facility shall be established as specified in paragraph (b)(6) of this
section.
(viii) The owner or operator of an affected facility shall conduct
an initial performance test for mercury emissions as required under
Sec. 60.8 of subpart A of this part.
(ix) Following the date that the initial performance test for
mercury is completed or is required to be completed under Sec. 60.8 of
subpart A of this part, the owner or operator of an affected facility
shall conduct a performance test for mercury emissions on a annual basis
(no more than 12 calendar months from the previous performance test).
(x) [Reserved]
(xi) The owner or operator of an affected facility where activated
carbon injection is used to comply with the mercury emission limit shall
follow the procedures specified in paragraph (m) of this section for
measuring and calculating carbon usage.
(e) The procedures and test methods specified in paragraphs (e)(1)
through (e)(14) of this section shall be used for determining compliance
with the sulfur dioxide emission limit under Sec. 60.52b(b)(1).
(1) The EPA Reference Method 19, section 4.3, shall be used to
calculate the daily geometric average sulfur dioxide emission
concentration.
(2) The EPA Reference Method 19, section 5.4, shall be used to
determine the daily geometric average percent reduction in the potential
sulfur dioxide emission concentration.
(3) The owner or operator of an affected facility may request that
compliance with the sulfur dioxide emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(4) The owner or operator of an affected facility shall conduct an
initial performance test for sulfur dioxide emissions as required under
Sec. 60.8 of subpart A of this part. Compliance with the sulfur dioxide
emission limit (concentration or percent reduction) shall be determined
by using the continuous emission monitoring system specified in
paragraph (e)(5) of this section to measure sulfur dioxide and
calculating a 24-hour daily geometric average emission concentration or
a 24-hour daily geometric average percent reduction using EPA Reference
Method 19, sections 4.3 and 5.4, as applicable.
(5) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous emission monitoring system
for measuring sulfur dioxide emissions discharged to the atmosphere and
record the output of the system.
(6) Following the date that the initial performance test for sulfur
dioxide is completed or is required to be completed under Sec. 60.8 of
subpart A of this part, compliance with the sulfur dioxide emission
limit shall be determined based on the 24-hour daily geometric average
of the hourly arithmetic average emission concentrations using
continuous emission monitoring system outlet data if compliance is based
on an emission concentration, or continuous emission monitoring system
inlet and outlet data if compliance is based on a percent reduction.
(7) At a minimum, valid continuous monitoring system hourly averages
shall be obtained as specified in paragraphs (e)(7)(i) and (e)(7)(ii)
for 75 percent of the operating hours per day for 90 percent of the
operating days per calendar quarter that the affected facility is
combusting municipal solid waste.
[[Page 178]]
(i) At least two data points per hour shall be used to calculate
each 1-hour arithmetic average.
(ii) Each sulfur dioxide 1-hour arithmetic average shall be
corrected to 7 percent oxygen on an hourly basis using the 1-hour
arithmetic average of the oxygen (or carbon dioxide) continuous emission
monitoring system data.
(8) The 1-hour arithmetic averages required under paragraph (e)(6)
of this section shall be expressed in parts per million corrected to 7
percent oxygen (dry basis) and used to calculate the 24-hour daily
geometric average emission concentrations and daily geometric average
emission percent reductions. The 1-hour arithmetic averages shall be
calculated using the data points required under Sec. 60.13(e)(2) of
subpart A of this part.
(9) All valid continuous emission monitoring system data shall be
used in calculating average emission concentrations and percent
reductions even if the minimum continuous emission monitoring system
data requirements of paragraph (e)(7) of this section are not met.
(10) The procedures under Sec. 60.13 of subpart A of this part shall
be followed for installation, evaluation, and operation of the
continuous emission monitoring system.
(11) The initial performance evaluation shall be completed no later
than 180 days after the date of initial startup of the municipal waste
combustor as specified under Sec. 60.8 of subpart A of this part.
(12) The continuous emission monitoring system shall be operated
according to Performance Specification 2 in appendix B of this part.
(i) During each relative accuracy test run of the continuous
emission monitoring system required by Performance Specification 2 in
appendix B of this part, sulfur dioxide and oxygen (or carbon dioxide)
data shall be collected concurrently (or within a 30- to 60-minute
period) by both the continuous emission monitors and the test methods
specified in paragraphs (e)(12)(i)(A) and (e)(12)(i)(B) of this section.
(A) For sulfur dioxide, EPA Reference Method 6, 6A, or 6C shall be
used.
(B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or
3B, as applicable shall be used.
(ii) The span value of the continuous emissions monitoring system at
the inlet to the sulfur dioxide control device shall be 125 percent of
the maximum estimated hourly potential sulfur dioxide emissions of the
municipal waste combustor unit. The span value of the continuous
emission monitoring system at the outlet of the sulfur dioxide control
device shall be 50 percent of the maximum estimated hourly potential
sulfur dioxide emissions of the municipal waste combustor unit.
(13) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with procedure 1 in appendix F of
this part.
(14) When sulfur dioxide emissions data are not obtained because of
continuous emission monitoring system breakdowns, repairs, calibration
checks, and zero and span adjustments, emissions data shall be obtained
by using other monitoring systems as approved by the Administrator or
EPA Reference Method 19 to provide, as necessary, valid emissions data
for a minimum of 75 percent of the hours per day that the affected
facility is operated and combusting municipal solid waste for 90 percent
of the days per calendar quarter that the affected facility is operated
and combusting municipal solid waste.
(f) The procedures and test methods specified in paragraphs (f)(1)
through (f)(8) of this section shall be used for determining compliance
with the hydrogen chloride emission limit under Sec. 60.52b(b)(2).
(1) The EPA Reference Method 26 or 26A, as applicable, shall be used
to determine the hydrogen chloride emission concentration. The minimum
sampling time shall be 1 hour.
(2) An oxygen (or carbon dioxide) measurement shall be obtained
simultaneously with each test run for hydrogen chloride required by
paragraph (f)(1) of this section.
(3) The percent reduction in potential hydrogen chloride emissions
(% PHCl) is computed using equation 2:
[[Page 179]]
[GRAPHIC] [TIFF OMITTED] TR19DE95.002
where:
%PHCl=percent reduction of the potential hydrogen chloride
emissions achieved.
Ei=potential hydrogen chloride emission concentration
measured at the control device inlet, corrected to 7 percent
oxygen (dry basis).
Eo=controlled hydrogen chloride emission concentration
measured at the control device outlet, corrected to 7 percent
oxygen (dry basis).
(4) The owner or operator of an affected facility may request that
compliance with the hydrogen chloride emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(5) As specified under Sec. 60.8 of subpart A of this part, all
performance tests shall consist of three test runs. The average of the
hydrogen chloride emission concentrations or percent reductions from the
three test runs is used to determine compliance.
(6) The owner or operator of an affected facility shall conduct an
initial performance test for hydrogen chloride as required under
Sec. 60.8 of subpart A of this part.
(7) Following the date that the initial performance test for
hydrogen chloride is completed or is required to be completed under
Sec. 60.8 of subpart A of this part, the owner or operator of an
affected facility shall conduct a performance test for hydrogen chloride
emissions on an annual basis (no more than 12 calendar months following
the previous performance test).
(8) [Reserved]
(g) The procedures and test methods specified in paragraphs (g)(1)
through (g)(9) of this section shall be used to determine compliance
with the limits for dioxin/furan emissions under Sec. 60.52b(c).
(1) The EPA Reference Method 1 shall be used for determining the
location and number of sampling points.
(2) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be
used for flue gas analysis.
(3) The EPA Reference Method 23 shall be used for determining the
dioxin/furan emission concentration.
(i) The minimum sample time shall be 4 hours per test run.
(ii) An oxygen (or carbon dioxide) measurement shall be obtained
simultaneously with each Method 23 test run for dioxins/furans.
(4) The owner or operator of an affected facility shall conduct an
initial performance test for dioxin/furan emissions in accordance with
paragraph (g)(3) of this section, as required under Sec. 60.8 of subpart
A of this part.
(5) Following the date that the initial performance test for
dioxins/furans is completed or is required to be completed under
Sec. 60.8 of subpart A of this part, the owner or operator of an
affected facility shall conduct performance tests for dioxin/furan
emissions in accordance with paragraph (g)(3) of this section, according
to one of the schedules specified in paragraphs (g)(5)(i) through
(g)(5)(iii) of this section.
(i) For affected facilities, performance tests shall be conducted on
an annual basis (no more than 12 calendar months following the previous
performance test.)
(ii) [Reserved]
(iii) Where all performance tests over a 2-year period indicate that
dioxin/furan emissions are less than or equal to 7 nanograms per dry
standard cubic meter (total mass) for all affected facilities located
within a municipal waste combustor plant, the owner or operator of the
municipal waste combustor plant may elect to conduct annual performance
tests for one affected facility (i.e., unit) per year at the municipal
waste combustor plant. At a minimum, a performance test for dioxin/furan
emissions shall be conducted annually (no more than 12 months following
the previous performance test) for one affected facility at the
municipal waste combustor plant. Each year a different affected facility
at the municipal waste combustor plant shall be tested, and the affected
facilities at the plant shall be tested in sequence (e.g., unit 1, unit
2, unit 3, as
[[Page 180]]
applicable). If each annual performance test continues to indicate a
dioxin/furan emission level less than or equal to 7 nanograms per dry
standard cubic meter (total mass), the owner or operator may continue
conducting a performance test on only one affected facility per year. If
any annual performance test indicates a dioxin/furan emission level
greater than 7 nanograms per dry standard cubic meter (total mass),
performance tests thereafter shall be conducted annually on all affected
facilities at the plant until and unless all annual performance tests
for all affected facilities at the plant over a 2-year period indicate a
dioxin/furan emission level less than or equal to 7 nanograms per dry
standard cubic meter (total mass).
(6) The owner or operator of an affected facility that selects to
follow the performance testing schedule specified in paragraph
(g)(5)(iii) of this section shall follow the procedures specified in
Sec. 60.59b(g)(4) for reporting the selection of this schedule.
(7) The owner or operator of an affected facility where activated
carbon is used to comply with the dioxin/furan emission limits specified
in Sec. 60.52b(c) or the dioxin/furan emission level specified in
paragraph (g)(5)(iii) of this section shall follow the procedures
specified in paragraph (m) of this section for measuring and calculating
the carbon usage rate.
(8) The owner or operator of an affected facility may request that
compliance with the dioxin/furan emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(9) As specified under Sec. 60.8 of subpart A of this part, all
performance tests shall consist of three test runs. The average of the
dioxin/furan emission concentrations from the three test runs is used to
determine compliance.
(h) The procedures and test methods specified in paragraphs (h)(1)
through (h)(12) of this section shall be used to determine compliance
with the nitrogen oxides emission limit for affected facilities under
Sec. 60.52b(d).
(1) The EPA Reference Method 19, section 4.1, shall be used for
determining the daily arithmetic average nitrogen oxides emission
concentration.
(2) The owner or operator of an affected facility may request that
compliance with the nitrogen oxides emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(3) The owner or operator of an affected facility subject to the
nitrogen oxides limit under Sec. 60.52b(d) shall conduct an initial
performance test for nitrogen oxides as required under Sec. 60.8 of
subpart A of this part. Compliance with the nitrogen oxides emission
limit shall be determined by using the continuous emission monitoring
system specified in paragraph (h)(4) of this section for measuring
nitrogen oxides and calculating a 24-hour daily arithmetic average
emission concentration using EPA Reference Method 19, section 4.1.
(4) The owner or operator of an affected facility subject to the
nitrogen oxides emission limit under Sec. 60.52b(d) shall install,
calibrate, maintain, and operate a continuous emission monitoring system
for measuring nitrogen oxides discharged to the atmosphere, and record
the output of the system.
(5) Following the date that the initial performance test for
nitrogen oxides is completed or is required to be completed under
Sec. 60.8 of subpart A of this part, compliance with the emission limit
for nitrogen oxides required under Sec. 60.52b(d) shall be determined
based on the 24-hour daily arithmetic average of the hourly emission
concentrations using continuous emission monitoring system outlet data.
(6) At a minimum, valid continuous emission monitoring system hourly
averages shall be obtained as specified in paragraphs (h)(6)(i) and
(h)(6)(ii) of this section for 75 percent of the operating hours per day
for 90 percent of the operating days per calendar quarter that the
affected facility is combusting municipal solid waste.
[[Page 181]]
(i) At least 2 data points per hour shall be used to calculate each
1-hour arithmetic average.
(ii) Each nitrogen oxides 1-hour arithmetic average shall be
corrected to 7 percent oxygen on an hourly basis using the 1-hour
arithmetic average of the oxygen (or carbon dioxide) continuous emission
monitoring system data.
(7) The 1-hour arithmetic averages required by paragraph (h)(5) of
this section shall be expressed in parts per million by volume (dry
basis) and used to calculate the 24-hour daily arithmetic average
concentrations. The 1-hour arithmetic averages shall be calculated using
the data points required under Sec. 60.13(e)(2) of subpart A of this
part.
(8) All valid continuous emission monitoring system data must be
used in calculating emission averages even if the minimum continuous
emission monitoring system data requirements of paragraph (h)(6) of this
section are not met.
(9) The procedures under Sec. 60.13 of subpart A of this part shall
be followed for installation, evaluation, and operation of the
continuous emission monitoring system. The initial performance
evaluation shall be completed no later than 180 days after the date of
initial startup of the municipal waste combustor unit, as specified
under Sec. 60.8 of subpart A of this part.
(10) The owner or operator of an affected facility shall operate the
continuous emission monitoring system according to Performance
Specification 2 in appendix B of this part and shall follow the
procedures and methods specified in paragraphs (h)(10)(i) and
(h)(10)(ii) of this section.
(i) During each relative accuracy test run of the continuous
emission monitoring system required by Performance Specification 2 of
appendix B of this part, nitrogen oxides and oxygen (or carbon dioxide)
data shall be collected concurrently (or within a 30- to 60-minute
period) by both the continuous emission monitors and the test methods
specified in paragraphs (h)(10)(i)(A) and (h)(10)(i)(B) of this section.
(A) For nitrogen oxides, EPA Reference Method 7, 7A, 7C, 7D, or 7E
shall be used.
(B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or
3B, as applicable shall be used.
(ii) The span value of the continuous emission monitoring system
shall be 125 percent of the maximum estimated hourly potential nitrogen
oxide emissions of the municipal waste combustor unit.
(11) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with procedure 1 in appendix F of
this part.
(12) When nitrogen oxides continuous emissions data are not obtained
because of continuous emission monitoring system breakdowns, repairs,
calibration checks, and zero and span adjustments, emissions data shall
be obtained using other monitoring systems as approved by the
Administrator or EPA Reference Method 19 to provide, as necessary, valid
emissions data for a minimum of 75 percent of the hours per day for 90
percent of the days per calendar quarter the unit is operated and
combusting municipal solid waste.
(i) The procedures specified in paragraphs (i)(1) through (i)(12) of
this section shall be used for determining compliance with the operating
requirements under Sec. 60.53b.
(1) Compliance with the carbon monoxide emission limits in
Sec. 60.53b(a) shall be determined using a 4-hour block arithmetic
average for all types of affected facilities except mass burn rotary
waterwall municipal waste combustors and refuse-derived fuel stokers.
(2) For affected mass burn rotary waterwall municipal waste
combustors and refuse-derived fuel stokers, compliance with the carbon
monoxide emission limits in Sec. 60.53b(a) shall be determined using a
24-hour daily arithmetic average.
(3) The owner or operator of an affected facility shall install,
calibrate, maintain, and operate a continuous emission monitoring system
for measuring carbon monoxide at the combustor outlet and record the
output of the system and shall follow the procedures and methods
specified in paragraphs (i)(3)(i) through (i)(3)(iii) of this section.
[[Page 182]]
(i) The continuous emission monitoring system shall be operated
according to Performance Specification 4A in appendix B of this part.
(ii) During each relative accuracy test run of the continuous
emission monitoring system required by Performance Specification 4A in
appendix B of this part, carbon monoxide and oxygen (or carbon dioxide)
data shall be collected concurrently (or within a 30- to 60-minute
period) by both the continuous emission monitors and the test methods
specified in paragraphs (i)(3)(ii)(A) and (i)(3)(ii)(B) of this section.
(A) For carbon monoxide, EPA Reference Method 10, 10A, or 10B shall
be used.
(B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or
3B, as applicable shall be used.
(iii) The span value of the continuous emission monitoring system
shall be 125 percent of the maximum estimated hourly potential carbon
monoxide emissions of the municipal waste combustor unit.
(4) The 4-hour block and 24-hour daily arithmetic averages specified
in paragraphs (i)(1) and (i)(2) of this section shall be calculated from
1-hour arithmetic averages expressed in parts per million by volume
corrected to 7 percent oxygen (dry basis). The 1-hour arithmetic
averages shall be calculated using the data points generated by the
continuous emission monitoring system. At least two data points shall be
used to calculate each 1-hour arithmetic average.
(5) The owner or operator of an affected facility may request that
compliance with the carbon monoxide emission limit be determined using
carbon dioxide measurements corrected to an equivalent of 7 percent
oxygen. The relationship between oxygen and carbon dioxide levels for
the affected facility shall be established as specified in paragraph
(b)(6) of this section.
(6) The procedures specified in paragraphs (i)(6)(i) through
(i)(6)(v) of this section shall be used to determine compliance with
load level requirements under Sec. 60.53b(b).
(i) The owner or operator of an affected facility with steam
generation capability shall install, calibrate, maintain, and operate a
steam flow meter or a feedwater flow meter; measure steam (or feedwater)
flow in kilograms per hour (or pounds per hour) on a continuous basis;
and record the output of the monitor. Steam (or feedwater) flow shall be
calculated in 4-hour block arithmetic averages.
(ii) The method included in the ``American Society of Mechanical
Engineers Power Test Codes: Test Code for Steam Generating Units, Power
Test Code 4.1--1964 (R1991)'' section 4 (incorporated by reference, see
Sec. 60.17 of subpart A of this part) shall be used for calculating the
steam (or feedwater) flow required under paragraph (i)(6)(i) of this
section. The recommendations in ``American Society of Mechanical
Engineers Interim Supplement 19.5 on Instruments and Apparatus:
Application, Part II of Fluid Meters, 6th edition (1971),'' chapter 4
(incorporated by reference--see Sec. 60.17 of subpart A of this part)
shall be followed for design, construction, installation, calibration,
and use of nozzles and orifices except as specified in (i)(6)(iii) of
this section.
(iii) Measurement devices such as flow nozzles and orifices are not
required to be recalibrated after they are installed.
(iv) All signal conversion elements associated with steam (or
feedwater flow) measurements must be calibrated according to the
manufacturer's instructions before each dioxin/furan performance test,
and at least once per year.
(7) To determine compliance with the maximum particulate matter
control device temperature requirements under Sec. 60.53b(c), the owner
or operator of an affected facility shall install, calibrate, maintain,
and operate a device for measuring on a continuous basis the temperature
of the flue gas stream at the inlet to each particulate matter control
device utilized by the affected facility. Temperature shall be
calculated in 4-hour block arithmetic averages.
(8) The maximum demonstrated municipal waste combustor unit load
shall be determined during the initial performance test for dioxins/
furans and each subsequent performance test during which compliance with
the dioxin/
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furan emission limit specified in Sec. 60.52b(c) is achieved. The
maximum demonstrated municipal waste combustor unit load shall be the
highest 4-hour arithmetic average load achieved during four consecutive
hours during the most recent test during which compliance with the
dioxin/furan emission limit was achieved.
(9) For each particulate matter control device employed at the
affected facility, the maximum demonstrated particulate matter control
device temperature shall be determined during the initial performance
test for dioxins/furans and each subsequent performance test during
which compliance with the dioxin/furan emission limit specified in
Sec. 60.52b(c) is achieved. The maximum demonstrated particulate matter
control device temperature shall be the highest 4-hour arithmetic
average temperature achieved at the particulate matter control device
inlet during four consecutive hours during the most recent test during
which compliance with the dioxin/furan limit was achieved.
(10) At a minimum, valid continuous emission monitoring system
hourly averages shall be obtained as specified in paragraphs (i)(10)(i)
and (i)(10)(ii) of this section for 75 percent of the operating hours
per day for 90 percent of the operating days per calendar quarter that
the affected facility is combusting municipal solid waste.
(i) At least two data points per hour shall be used to calculate
each 1-hour arithmetic average.
(ii) At a minimum, each carbon monoxide 1-hour arithmetic average
shall be corrected to 7 percent oxygen on an hourly basis using the 1-
hour arithmetic average of the oxygen (or carbon dioxide) continuous
emission monitoring system data.
(11) All valid continuous emission monitoring system data must be
used in calculating the parameters specified under paragraph (i) of this
section even if the minimum data requirements of paragraph (i)(10) of
this section are not met. When carbon monoxide continuous emission data
are not obtained because of continuous emission monitoring system
breakdowns, repairs, calibration checks, and zero and span adjustments,
emissions data shall be obtained using other monitoring systems as
approved by the Administrator or EPA Reference Method 10 to provide, as
necessary, the minimum valid emission data.
(12) Quarterly accuracy determinations and daily calibration drift
tests for the carbon monoxide continuous emission monitoring system
shall be performed in accordance with procedure 1 in appendix F of this
part.
(j) The procedures specified in paragraphs (j)(1) and (j)(2) of this
section shall be used for calculating municipal waste combustor unit
capacity as defined under Sec. 60.51b.
(1) For municipal waste combustor units capable of combusting
municipal solid waste continuously for a 24-hour period, municipal waste
combustor unit capacity shall be calculated based on 24 hours of
operation at the maximum charging rate. The maximum charging rate shall
be determined as specified in paragraphs (j)(1)(i) and (j)(1)(ii) of
this section as applicable.
(i) For combustors that are designed based on heat capacity, the
maximum charging rate shall be calculated based on the maximum design
heat input capacity of the unit and a heating value of 12,800 kilojoules
per kilogram for combustors firing refuse-derived fuel and a heating
value of 10,500 kilojoules per kilogram for combustors firing municipal
solid waste that is not refuse-derived fuel.
(ii) For combustors that are not designed based on heat capacity,
the maximum charging rate shall be the maximum design charging rate.
(2) For batch feed municipal waste combustor units, municipal waste
combustor unit capacity shall be calculated as the maximum design amount
of municipal solid waste that can be charged per batch multiplied by the
maximum number of batches that could be processed in a 24-hour period.
The maximum number of batches that could be processed in a 24-hour
period is calculated as 24 hours divided by the design number of hours
required to process one batch of municipal solid waste, and may include
fractional batches (e.g., if one batch requires 16 hours, then 24/16, or
1.5 batches, could be combusted in a 24-hour period). For batch
combustors that are designed
[[Page 184]]
based on heat capacity, the design heating value of 12,800 kilojoules
per kilogram for combustors firing refuse-derived fuel and a heating
value of 10,500 kilojoules per kilogram for combustors firing municipal
solid waste that is not refuse-derived fuel shall be used in calculating
the municipal waste combustor unit capacity in megagrams per day of
municipal solid waste.
(k) The procedures specified in paragraphs (k)(1) through (k)(4) of
this section shall be used for determining compliance with the fugitive
ash emission limit under Sec. 60.55b.
(1) The EPA Reference Method 22 shall be used for determining
compliance with the fugitive ash emission limit under Sec. 60.55b. The
minimum observation time shall be a series of three 1-hour observations.
The observation period shall include times when the facility is
transferring ash from the municipal waste combustor unit to the area
where ash is stored or loaded into containers or trucks.
(2) The average duration of visible emissions per hour shall be
calculated from the three 1-hour observations. The average shall be used
to determine compliance with Sec. 60.55b.
(3) The owner or operator of an affected facility shall conduct an
initial performance test for fugitive ash emissions as required under
Sec. 60.8 of subpart A of this part.
(4) Following the date that the initial performance test for
fugitive ash emissions is completed or is required to be completed under
Sec. 60.8 of subpart A of this part for an affected facility, the owner
or operator shall conduct a performance test for fugitive ash emissions
on an annual basis (no more than 12 calendar months following the
previous performance test).
(l) The procedures specified in paragraphs (l)(1) through (l)(3) of
this section shall be used to determine compliance with the opacity
limit for air curtain incinerators under Sec. 60.56b.
(1) The EPA Reference Method 9 shall be used for determining
compliance with the opacity limit.
(2) The owner or operator of the air curtain incinerator shall
conduct an initial performance test for opacity as required under
Sec. 60.8 of subpart A of this part.
(3) Following the date that the initial performance test is
completed or is required to be completed under Sec. 60.8 of subpart A of
this part, the owner or operator of the air curtain incinerator shall
conduct a performance test for opacity on an annual basis (no more than
12 calendar months following the previous performance test).
(m) The owner or operator of an affected facility where activated
carbon injection is used to comply with the mercury emission limit under
Sec. 60.52b(a)(5), or the dioxin/furan emission limits under
Sec. 60.52(b)(c), or the dioxin/furan emission level specified in
Sec. 60.58b(g)(5)(iii) shall follow the procedures specified in
paragraphs (m)(1) through (m)(3) of this section.
(1) During the performance tests for dioxins/furans and mercury, as
applicable, the owner or operator shall estimate an average carbon mass
feed rate based on carbon injection system operating parameters such as
the screw feeder speed, hopper volume, hopper refill frequency, or other
parameters appropriate to the feed system being employed, as specified
in paragraphs (m)(1)(i) and (m)(1)(ii) of this section.
(i) An average carbon mass feed rate in kilograms per hour or pounds
per hour shall be estimated during the initial performance test for
mercury emissions and each subsequent performance test for mercury
emissions.
(ii) An average carbon mass feed rate in kilograms per hour or
pounds per hour shall be estimated during the initial performance test
for dioxin/furan emissions and each subsequent performance test for
dioxin/furan emissions.
(2) During operation of the affected facility, the carbon injection
system operating parameter(s) that are the primary indicator(s) of the
carbon mass feed rate (e.g., screw feeder setting) must equal or exceed
the level(s) documented during the performance tests specified under
paragraphs (m)(1)(i) and (m)(1)(ii) of this section.
(3) The owner or operator of an affected facility shall estimate the
total carbon usage of the plant (kilograms or pounds) for each calendar
quarter by two independent methods, according to
[[Page 185]]
the procedures in paragraphs (m)(3)(i) and (m)(3)(ii) of this section.
(i) The weight of carbon delivered to the plant.
(ii) Estimate the average carbon mass feed rate in kilograms per
hour or pounds per hour for each hour of operation for each affected
facility based on the parameters specified under paragraph (m)(1) of
this section, and sum the results for all affected facilities at the
plant for the total number of hours of operation during the calendar
quarter.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997;
65 FR 61753, Oct. 17, 2000]
Sec. 60.59b Reporting and recordkeeping requirements.
(a) The owner or operator of an affected facility with a capacity to
combust greater than 250 tons per day shall submit, on or before the
date the application for a construction permit is submitted under 40 CFR
part 51, subpart I, or part 52, as applicable, the items specified in
paragraphs (a)(1) through (a)(4) of this section.
(1) The preliminary and final draft materials separation plans
required by Sec. 60.57b(a)(1) and (a)(5).
(2) A copy of the notification of the public meeting required by
Sec. 60.57b(a)(1)(ii).
(3) A transcript of the public meeting required by
Sec. 60.57b(a)(2).
(4) A copy of the document summarizing responses to public comments
required by Sec. 60.57b(a)(3).
(b) The owner or operator of an affected facility with a capacity to
combust greater than 250 tons per day shall submit a notification of
construction, which includes the information specified in paragraphs
(b)(1) through (b)(5) of this section.
(1) Intent to construct.
(2) Planned initial startup date.
(3) The types of fuels that the owner or operator plans to combust
in the affected facility.
(4) The municipal waste combustor unit capacity, and supporting
capacity calculations prepared in accordance with Sec. 60.58b(j).
(5) Documents associated with the siting requirements under
Sec. 60.57b (a) and (b), as specified in paragraphs (b)(5)(i) through
(b)(5)(v) of this section.
(i) The siting analysis required by Sec. 60.57b (b)(1) and (b)(2).
(ii) The final materials separation plan for the affected facility
required by Sec. 60.57b(a)(10).
(iii) A copy of the notification of the public meeting required by
Sec. 60.57b(b)(3)(ii).
(iv) A transcript of the public meeting required by
Sec. 60.57b(b)(4).
(v) A copy of the document summarizing responses to public comments
required by Sec. 60.57b (a)(9) and (b)(5).
(c) The owner or operator of an air curtain incinerator subject to
the opacity limit under Sec. 60.56b shall provide a notification of
construction that includes the information specified in paragraphs
(b)(1) through (b)(4) of this section.
(d) The owner or operator of an affected facility subject to the
standards under Secs. 60.52b, 60.53b, 60.54b, 60.55b, and 60.57b shall
maintain records of the information specified in paragraphs (d)(1)
through (d)(15) of this section, as applicable, for each affected
facility for a period of at least 5 years.
(1) The calendar date of each record.
(2) The emission concentrations and parameters measured using
continuous monitoring systems as specified under paragraphs (d)(2)(i)
and (d)(2)(ii) of this section.
(i) The measurements specified in paragraphs (d)(2)(i)(A) through
(d)(2)(i)(D) of this section shall be recorded and be available for
submittal to the Administrator or review onsite by an inspector.
(A) All 6-minute average opacity levels as specified under
Sec. 60.58b(c).
(B) All 1-hour average sulfur dioxide emission concentrations as
specified under Sec. 60.58b(e).
(C) All 1-hour average nitrogen oxides emission concentrations as
specified under Sec. 60.58b(h).
(D) All 1-hour average carbon monoxide emission concentrations,
municipal waste combustor unit load measurements, and particulate matter
control device inlet temperatures as specified under Sec. 60.58b(i).
(ii) The average concentrations and percent reductions, as
applicable, specified in paragraphs (d)(2)(ii)(A) through
[[Page 186]]
(d)(2)(ii)(D) of this section shall be computed and recorded, and shall
be available for submittal to the Administrator or review on-site by an
inspector.
(A) All 24-hour daily geometric average sulfur dioxide emission
concentrations and all 24-hour daily geometric average percent
reductions in sulfur dioxide emissions as specified under
Sec. 60.58b(e).
(B) All 24-hour daily arithmetic average nitrogen oxides emission
concentrations as specified under Sec. 60.58b(h).
(C) All 4-hour block or 24-hour daily arithmetic average carbon
monoxide emission concentrations, as applicable, as specified under
Sec. 60.58b(i).
(D) All 4-hour block arithmetic average municipal waste combustor
unit load levels and particulate matter control device inlet
temperatures as specified under Sec. 60.58b(i).
(3) Identification of the calendar dates when any of the average
emission concentrations, percent reductions, or operating parameters
recorded under paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) of this
section, or the opacity levels recorded under paragraph (d)(2)(i)(A) of
this section are above the applicable limits, with reasons for such
exceedances and a description of corrective actions taken.
(4) For affected facilities that apply activated carbon for mercury
or dioxin/furan control, the records specified in paragraphs (d)(4)(i)
through (d)(4)(v) of this section.
(i) The average carbon mass feed rate (in kilograms per hour or
pounds per hour) estimated as required under Sec. 60.58b(m)(1)(i) of
this section during the initial mercury performance test and all
subsequent annual performance tests, with supporting calculations.
(ii) The average carbon mass feed rate (in kilograms per hour or
pounds per hour) estimated as required under Sec. 60.58b(m)(1)(ii) of
this section during the initial dioxin/furan performance test and all
subsequent annual performance tests, with supporting calculations.
(iii) The average carbon mass feed rate (in kilograms per hour or
pounds per hour) estimated for each hour of operation as required under
Sec. 60.58b(m)(3)(ii) of this section, with supporting calculations.
(iv) The total carbon usage for each calendar quarter estimated as
specified by paragraph 60.58b(m)(3) of this section, with supporting
calculations.
(v) Carbon injection system operating parameter data for the
parameter(s) that are the primary indicator(s) of carbon feed rate
(e.g., screw feeder speed).
(5) [Reserved]
(6) Identification of the calendar dates for which the minimum
number of hours of any of the data specified in paragraphs (d)(6)(i)
through (d)(6)(v) of this section have not been obtained including
reasons for not obtaining sufficient data and a description of
corrective actions taken.
(i) Sulfur dioxide emissions data;
(ii) Nitrogen oxides emissions data;
(iii) Carbon monoxide emissions data;
(iv) Municipal waste combustor unit load data; and
(v) Particulate matter control device temperature data.
(7) Identification of each occurrence that sulfur dioxide emissions
data, nitrogen oxides emissions data (large municipal waste combustors
only), or operational data (i.e., carbon monoxide emissions, unit load,
and particulate matter control device temperature) have been excluded
from the calculation of average emission concentrations or parameters,
and the reasons for excluding the data.
(8) The results of daily drift tests and quarterly accuracy
determinations for sulfur dioxide, nitrogen oxides, and carbon monoxide
continuous emission monitoring systems, as required under appendix F of
this part, procedure 1.
(9) The test reports documenting the results of the initial
performance test and all annual performance tests listed in paragraphs
(d)(9)(i) and (d)(9)(ii) of this section shall be recorded along with
supporting calculations.
(i) The results of the initial performance test and all annual
performance tests conducted to determine compliance with the particulate
matter, opacity, cadmium, lead, mercury, dioxins/furans, hydrogen
chloride, and fugitive ash emission limits.
(ii) For the initial dioxin/furan performance test and all
subsequent
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dioxin/furan performance tests recorded under paragraph (d)(9)(i) of
this section, the maximum demonstrated municipal waste combustor unit
load and maximum demonstrated particulate matter control device
temperature (for each particulate matter control device).
(10) [Reserved]
(11) For each affected facility subject to the siting provisions
under Sec. 60.57b, the siting analysis, the final materials separation
plan, a record of the location and date of the public meetings, and the
documentation of the responses to public comments received at the public
meetings.
(12) The records specified in paragraphs (d)(12)(i) through
(d)(12)(iii) of this section.
(i) Records showing the names of the municipal waste combustor chief
facility operator, shift supervisors, and control room operators who
have been provisionally certified by the American Society of Mechanical
Engineers or an equivalent State-approved certification program as
required by Sec. 60.54b(a) including the dates of initial and renewal
certifications and documentation of current certification.
(ii) Records showing the names of the municipal waste combustor
chief facility operator, shift supervisors, and control room operators
who have been fully certified by the American Society of Mechanical
Engineers or an equivalent State-approved certification program as
required by Sec. 60.54b(b) including the dates of initial and renewal
certifications and documentation of current certification.
(iii) Records showing the names of the municipal waste combustor
chief facility operator, shift supervisors, and control room operators
who have completed the EPA municipal waste combustor operator training
course or a State-approved equivalent course as required by
Sec. 60.54b(d) including documentation of training completion.
(13) Records showing the names of persons who have completed a
review of the operating manual as required by Sec. 60.54b(f) including
the date of the initial review and subsequent annual reviews.
(14) For affected facilities that apply activated carbon for mercury
or dioxin/furan control, identification of the calendar dates when the
average carbon mass feed rates recorded under (d)(4)(iii) of this
section were less than either of the hourly carbon feed rates estimated
during performance tests for mercury or dioxin/furan emissions and
recorded under paragraphs (d)(4)(i) and (d)(4)(ii) of this section,
respectively, with reasons for such feed rates and a description of
corrective actions taken.
(15) For affected facilities that apply activated carbon for mercury
or dioxin/furan control, identification of the calendar dates when the
carbon injection system operating parameter(s) that are the primary
indicator(s) of carbon mass feed rate (e.g., screw feeder speed)
recorded under paragraph (d)(4)(v) of this section are below the
level(s) estimated during the performance tests as specified in
Sec. 60.58b(m)(1)(i) and Sec. 60.58b(m)(1)(ii) of this section, with
reasons for such occurrences and a description of corrective actions
taken.
(e) The owner or operator of an air curtain incinerator subject to
the opacity limit under Sec. 60.56b shall maintain records of results of
the initial opacity performance test and subsequent performance tests
required by Sec. 60.58b(l) for a period of at least 5 years.
(f) The owner or operator of an affected facility shall submit the
information specified in paragraphs (f)(1) through (f)(6) of this
section in the initial performance test report.
(1) The initial performance test data as recorded under paragraphs
(d)(2)(ii)(A) through (d)(2)(ii)(D) of this section for the initial
performance test for sulfur dioxide, nitrogen oxides, carbon monoxide,
municipal waste combustor unit load level, and particulate matter
control device inlet temperature.
(2) The test report documenting the initial performance test
recorded under paragraph (d)(9) of this section for particulate matter,
opacity, cadmium, lead, mercury, dioxins/furans, hydrogen chloride, and
fugitive ash emissions.
(3) The performance evaluation of the continuous emission monitoring
system using the applicable performance specifications in appendix B of
this part.
(4) The maximum demonstrated municipal waste combustor unit load and
[[Page 188]]
maximum demonstrated particulate matter control device inlet
temperature(s) established during the initial dioxin/furan performance
test as recorded under paragraph (d)(9) of this section.
(5) For affected facilities that apply activated carbon injection
for mercury control, the owner or operator shall submit the average
carbon mass feed rate recorded under paragraph (d)(4)(i) of this
section.
(6) For those affected facilities that apply activated carbon
injection for dioxin/furan control, the owner or operator shall submit
the average carbon mass feed rate recorded under paragraph (d)(4)(ii) of
this section.
(g) Following the first year of municipal combustor operation, the
owner or operator of an affected facility shall submit an annual report
including the information specified in paragraphs (g)(1) through (g)(4)
of this section, as applicable, no later than February 1 of each year
following the calendar year in which the data were collected (once the
unit is subject to permitting requirements under Title V of the Act, the
owner or operator of an affected facility must submit these reports
semiannually).
(1) A summary of data collected for all pollutants and parameters
regulated under this subpart, which includes the information specified
in paragraphs (g)(1)(i) through (g)(1)(v) of this section.
(i) A list of the particulate matter, opacity, cadmium, lead,
mercury, dioxins/furans, hydrogen chloride, and fugitive ash emission
levels achieved during the performance tests recorded under paragraph
(d)(9) of this section.
(ii) A list of the highest emission level recorded for sulfur
dioxide, nitrogen oxides, carbon monoxide, municipal waste combustor
unit load level, and particulate matter control device inlet temperature
based on the data recorded under paragraphs (d)(2)(ii)(A) through
(d)(2)(ii)(D) of this section.
(iii) List the highest opacity level measured, based on the data
recorded under paragraph (d)(2)(i)(A) of this section.
(iv) The total number of days that the minimum number of hours of
data for sulfur dioxide, nitrogen oxides, carbon monoxide, municipal
waste combustor unit load, and particulate matter control device
temperature data were not obtained based on the data recorded under
paragraph (d)(6) of this section.
(v) The total number of hours that data for sulfur dioxide, nitrogen
oxides, carbon monoxide, municipal waste combustor unit load, and
particulate matter control device temperature were excluded from the
calculation of average emission concentrations or parameters based on
the data recorded under paragraph (d)(7) of this section.
(2) The summary of data reported under paragraph (g)(1) of this
section shall also provide the types of data specified in paragraphs
(g)(1)(i) through (g)(1)(vi) of this section for the calendar year
preceding the year being reported, in order to provide the Administrator
with a summary of the performance of the affected facility over a 2-year
period.
(3) The summary of data including the information specified in
paragraphs (g)(1) and (g)(2) of this section shall highlight any
emission or parameter levels that did not achieve the emission or
parameter limits specified under this subpart.
(4) A notification of intent to begin the reduced dioxin/furan
performance testing schedule specified in Sec. 60.58b(g)(5)(iii) of this
section during the following calendar year.
(h) The owner or operator of an affected facility shall submit a
semiannual report that includes the information specified in paragraphs
(h)(1) through (h)(5) of this section for any recorded pollutant or
parameter that does not comply with the pollutant or parameter limit
specified under this subpart, according to the schedule specified under
paragraph (h)(6) of this section.
(1) The semiannual report shall include information recorded under
paragraph (d)(3) of this section for sulfur dioxide, nitrogen oxides,
carbon monoxide, municipal waste combustor unit load level, particulate
matter control device inlet temperature, and opacity.
(2) For each date recorded as required by paragraph (d)(3) of this
section and reported as required by paragraph (h)(1) of this section,
the semiannual
[[Page 189]]
report shall include the sulfur dioxide, nitrogen oxides, carbon
monoxide, municipal waste combustor unit load level, particulate matter
control device inlet temperature, or opacity data, as applicable,
recorded under paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) and
(d)(2)(i)(A) of this section, as applicable.
(3) If the test reports recorded under paragraph (d)(9) of this
section document any particulate matter, opacity, cadmium, lead,
mercury, dioxins/furans, hydrogen chloride, and fugitive ash emission
levels that were above the applicable pollutant limits, the semiannual
report shall include a copy of the test report documenting the emission
levels and the corrective actions taken.
(4) The semiannual report shall include the information recorded
under paragraph (d)(15) of this section for the carbon injection system
operating parameter(s) that are the primary indicator(s) of carbon mass
feed rate.
(5) For each operating date reported as required by paragraph (h)(4)
of this section, the semiannual report shall include the carbon feed
rate data recorded under paragraph (d)(4)(iii) of this section.
(6) Semiannual reports required by paragraph (h) of this section
shall be submitted according to the schedule specified in paragraphs
(h)(6)(i) and (h)(6)(ii) of this section.
(i) If the data reported in accordance with paragraphs (h)(1)
through (h)(5) of this section were collected during the first calendar
half, then the report shall be submitted by August 1 following the first
calendar half.
(ii) If the data reported in accordance with paragraphs (h)(1)
through (h)(5) of this section were collected during the second calendar
half, then the report shall be submitted by February 1 following the
second calendar half.
(i) The owner or operator of an air curtain incinerator subject to
the opacity limit under Sec. 60.56b shall submit the results of the
initial opacity performance test and all subsequent annual performance
tests recorded under paragraph (e) of this section. Annual performance
tests shall be submitted by February 1 of the year following the year of
the performance test.
(j) All reports specified under paragraphs (a), (b), (c), (f), (g),
(h), and (i) of this section shall be submitted as a paper copy,
postmarked on or before the submittal dates specified under these
paragraphs, and maintained onsite as a paper copy for a period of 5
years.
(k) All records specified under paragraphs (d) and (e) of this
section shall be maintained onsite in either paper copy or computer-
readable format, unless an alternative format is approved by the
Administrator.
(l) If the owner or operator of an affected facility would prefer a
different annual or semiannual date for submitting the periodic reports
required by paragraphs (g), (h) and (i) of this section, then the dates
may be changed by mutual agreement between the owner or operator and the
Administrator according to the procedures specified in Sec. 60.19(c) of
subpart A of this part.
[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45127, Aug. 25,
1997]
Subpart Ec--Standards of Performance for Hospital/Medical/Infectious
Waste Incinerators for Which Construction is Commenced After June 20,
1996
Source: 62 FR 48382, Sept. 15, 1997, unless otherwise noted.
Sec. 60.50c Applicability and delegation of authority.
(a) Except as provided in paragraphs (b) through (h) of this
section, the affected facility to which this subpart applies is each
individual hospital/medical/infectious waste incinerator (HMIWI) for
which construction is commenced after June 20, 1996 or for which
modification is commenced after March 16, 1998.
(b) A combustor is not subject to this subpart during periods when
only pathological waste, low-level radioactive waste, and/or
chemotherapeutic waste (all defined in Sec. 60.51c) is burned, provided
the owner or operator of the combustor:
(1) Notifies the Administrator of an exemption claim; and
(2) Keeps records on a calendar quarter basis of the periods of time
when
[[Page 190]]
only pathological waste, low-level radioactivewaste and/or
chemotherapeutic waste is burned.
(c) Any co-fired combustor (defined in Sec. 60.51c) is not subject
to this subpart if the owner or operator of the co-fired combustor:
(1) Notifies the Administrator of an exemption claim;
(2) Provides an estimate of the relative amounts of hospital waste,
medical/infectious waste, and other fuels and wastes to be combusted;
and
(3) Keeps records on a calendar quarter basis of the weight of
hospital waste and medical/infectious waste combusted, and the weight of
all other fuels and wastes combusted at the co-fired combustor.
(d) Any combustor required to have a permit under section 3005 of
the Solid Waste Disposal Act is not subject to this subpart.
(e) Any combustor which meets the applicability requirements under
subpart Cb, Ea, or Eb of this part (standards or guidelines for certain
municipal waste combustors) is not subject to this subpart.
(f) Any pyrolysis unit (defined in Sec. 60.51c) is not subject to
this subpart.
(g) Cement kilns firing hospital waste and/or medical/infectious
waste are not subject to this subpart.
(h) Physical or operational changes made to an existing HMIWI solely
for the purpose of complying with emission guidelines under subpart Ce
are not considered a modification and do not result in an existing HMIWI
becoming subject to this subpart.
(i) In delegating implementation and enforcement authority to a
State under section 111(c) of the Clean Air Act, the following
authorities shall be retained by the Administrator and not transferred
to a State:
(1) The requirements of Sec. 60.56c(i) establishing operating
parameters when using controls other than those listed in
Sec. 60.56c(d).
(2) Alternative methods of demonstrating compliance under Sec. 60.8.
(j) Affected facilities subject to this subpart are not subject to
the requirements of 40 CFR part 64.
(k) The requirements of this subpart shall become effective March
16, 1998
(l) Beginning September 15, 2000, or on the effective date of an
EPA-approved operating permit program under Clean Air Act title V and
the implementing regulations under 40 CFR part 70 in the State in which
the unit is located, whichever date is later, affected facilities
subject to this subpart shall operate pursuant to a permit issued under
the EPA approved State operating permit program.
Sec. 60.51c Definitions.
Batch HMIWI means an HMIWI that is designed such that neither waste
charging nor ash removal can occur during combustion.
Biologicals means preparations made from living organisms and their
products, including vaccines, cultures, etc., intended for use in
diagnosing, immunizing, or treating humans or animals or in research
pertaining thereto.
Blood products means any product derived from human blood, including
but not limited to blood plasma, platelets, red or white blood
corpuscles, and other derived licensed products, such as interferon,
etc.
Body fluids means liquid emanating or derived from humans and
limited to blood; dialysate; amniotic, cerebrospinal, synovial, pleural,
peritoneal and pericardial fluids; and semen and vaginal secretions.
Bypass stack means a device used for discharging combustion gases to
avoid severe damage to the air pollution control device or other
equipment.
Chemotherapeutic waste means waste material resulting from the
production or use of antineoplastic agents used for the purpose of
stopping or reversing the growth of malignant cells.
Co-fired combustor means a unit combusting hospital waste and/or
medical/infectious waste with other fuels or wastes (e.g., coal,
municipal solid waste) and subject to an enforceable requirement
limiting the unit to combusting a fuel feed stream, 10 percent or less
of the weight of which is comprised, in aggregate, of hospital waste and
medical/infectious waste as measured on a calendar quarter basis. For
purposes of this definition, pathological waste, chemotherapeutic waste,
and low-level radioactive waste are
[[Page 191]]
considered ``other'' wastes when calculating the percentage of hospital
waste and medical/infectious waste combusted.
Continuous emission monitoring system or CEMS means a monitoring
system for continuously measuring and recording the emissions of a
pollutant from an affected facility.
Continuous HMIWI means an HMIWI that is designed to allow waste
charging and ash removal during combustion.
Dioxins/furans means the combined emissions of tetra-through octa-
chlorinated dibenzo-para-dioxins and dibenzofurans, as measured by EPA
Reference Method 23.
Dry scrubber means an add-on air pollution control system that
injects dry alkaline sorbent (dry injection) or sprays an alkaline
sorbent (spray dryer) to react with and neutralize acid gases in the
HMIWI exhaust stream forming a dry powder material.
Fabric filter or baghouse means an add-on air pollution control
system that removes particulate matter (PM) and nonvaporous metals
emissions by passing flue gas through filter bags.
Facilities manager means the individual in charge of purchasing,
maintaining, and operating the HMIWI or the owner's or operator's
representative responsible for the management of the HMIWI. Alternative
titles may include director of facilities or vice president of support
services.
High-air phase means the stage of the batch operating cycle when the
primary chamber reaches and maintains maximum operating temperatures.
Hospital means any facility which has an organized medical staff,
maintains at least six inpatient beds, and where the primary function of
the institution is to provide diagnostic and therapeutic patient
services and continuous nursing care primarily to human inpatients who
are not related and who stay on average in excess of 24 hours per
admission. This definition does not include facilities maintained for
the sole purpose of providing nursing or convalescent care to human
patients who generally are not acutely ill but who require continuing
medical supervision.
Hospital/medical/infectious waste incinerator or HMIWI or HMIWI unit
means any device that combusts any amount of hospital waste and/or
medical/infectious waste.
Hospital/medical/infectious waste incinerator operator or HMIWI
operator means any person who operates, controls or supervises the day-
to-day operation of an HMIWI.
Hospital waste means discards generated at a hospital, except unused
items returned to the manufacturer. The definition of hospital waste
does not include human corpses, remains, and anatomical parts that are
intended for interment or cremation.
Infectious agent means any organism (such as a virus or bacteria)
that is capable of being communicated by invasion and multiplication in
body tissues and capable of causing disease or adverse health impacts in
humans.
Intermittent HMIWI means an HMIWI that is designed to allow waste
charging, but not ash removal, during combustion.
Large HMIWI means:
(1) Except as provided in (2);
(i) An HMIWI whose maximum design waste burning capacity is more
than 500 pounds per hour; or
(ii) A continuous or intermittent HMIWI whose maximum charge rate is
more than 500 pounds per hour; or
(iii) A batch HMIWI whose maximum charge rate is more than 4,000
pounds per day.
(2) The following are not large HMIWI:
(i) A continuous or intermittent HMIWI whose maximum charge rate is
less than or equal to 500 pounds per hour; or
(ii) A batch HMIWI whose maximum charge rate is less than or equal
to 4,000 pounds per day.
Low-level radioactive waste means waste material which contains
radioactive nuclides emitting primarily beta or gamma radiation, or
both, in concentrations or quantities that exceed applicable federal or
State standards for unrestricted release. Low-level radioactive waste is
not high-level radioactive waste, spent nuclear fuel, or by-product
material as defined by the Atomic Energy Act of 1954 (42 U.S.C.
2014(e)(2)).
[[Page 192]]
Malfunction means any sudden, infrequent, and not reasonably
preventable failure of air pollution control equipment, process
equipment, or a process to operate in a normal or usual manner. Failures
that are caused, in part, by poor maintenance or careless operation are
not malfunctions. During periods of malfunction the operator shall
operate within established parameters as much as possible, and
monitoring of all applicable operating parameters shall continue until
all waste has been combusted or until the malfunction ceases, whichever
comes first.
Maximum charge rate means:
(1) For continuous and intermittent HMIWI, 110 percent of the lowest
3-hour average charge rate measured during the most recent performance
test demonstrating compliance with all applicable emission limits.
(2) For batch HMIWI, 110 percent of the lowest daily charge rate
measured during the most recent performance test demonstrating
compliance with all applicable emission limits.
Maximum design waste burning capacity means:
(1) For intermittent and continuous HMIWI,
C=PV x 15,000/8,500
Where:
C=HMIWI capacity, lb/hr
PV=primary chamber volume, ft\3\
15,000=primary chamber heat release rate factor, Btu/ft\3\/hr
68,500=standard waste heating value, Btu/lb;
(2) For batch HMIWI,
C=PV x 4.5/8
Where:
C=HMIWI capacity, lb/hr
PV=primary chamber volume, ft\3\
164.5=waste density, lb/ft\3\
8=typical hours of operation of a batch HMIWI, hours.
Maximum fabric filter inlet temperature means 110 percent of the
lowest 3-hour average temperature at the inlet to the fabric filter
(taken, at a minimum, once every minute) measured during the most recent
performance test demonstrating compliance with the dioxin/furan emission
limit.
Maximum flue gas temperature means 110 percent of the lowest 3-hour
average temperature at the outlet from the wet scrubber (taken, at a
minimum, once every minute) measured during the most recent performance
test demonstrating compliance with the mercury (Hg) emission limit.
Medical/infectious waste means any waste generated in the diagnosis,
treatment, or immunization of human beings or animals, in research
pertaining thereto, or in the production or testing of biologicals that
is listed in paragraphs (1) through (7) of this definition. The
definition of medical/infectious waste does not include hazardous waste
identified or listed under the regulations in part 261 of this chapter;
household waste, as defined in Sec. 261.4(b)(1) of this chapter; ash
from incineration of medical/infectious waste, once the incineration
process has been completed; human corpses, remains, and anatomical parts
that are intended for interment mation; and domestic sewage materials
identified in Sec. 261.4(a)(1) of this chapter.
(1) Cultures and stocks of infectious agents and associated
biologicals, including: cultures from medical and pathological
laboratories; cultures and stocks of infectious agents from research and
industrial laboratories; wastes from the production of biologicals;
discarded live and attenuated vaccines; and culture dishes and devices
used to transfer, inoculate, and mix cultures.
(2) Human pathological waste, including tissues, organs, and body
parts and body fluids that are removed during surgery or autopsy, or
other medical procedures, and specimens of body fluids and their
containers.
(3) Human blood and blood products including:
(i) Liquid waste human blood;
(ii) Products of blood;
(iii) Items saturated and/or dripping with human blood; or
(iv) Items that were saturated and/or dripping with human blood that
are now caked with dried human blood; including serum, plasma, and other
blood components, and their containers, which were used or intended for
use in either patient care, testing and laboratory analysis or the
development of pharmaceuticals. Intravenous bags are also include in
this category.
[[Page 193]]
(4) Sharps that have been used in animal or human patient care or
treatment or in medical, research, or industrial laboratories, including
hypodermic needles, syringes (with or without the attached needle),
pasteur pipettes, scalpel blades, blood vials, needles with attached
tubing, and culture dishes (regardless of presence of infectious
agents). Also included are other types of broken or unbroken glassware
that were in contact with infectious agents, such as used slides and
cover slips.
(5) Animal waste including contaminated animal carcasses, body
parts, and bedding of animals that were known to have been exposed to
infectious agents during research (including research in veterinary
hospitals), production of biologicals or testing of pharmaceuticals.
(6) Isolation wastes including biological waste and discarded
materials contaminated with blood, excretions, exudates, or secretions
from humans who are isolated to protect others from certain highly
communicable diseases, or isolated animals known to be infected with
highly communicable diseases.
(7) Unused sharps including the following unused, discarded sharps:
hypodermic needles, suture needles, syringes, and scalpel blades.
Medium HMIWI means:
(1) Except as provided in paragraph (2);
(i) An HMIWI whose maximum design waste burning capacity is more
than 200 pounds per hour but less than or equal to 500 pounds per hour;
or
(ii) A continuous or intermittent HMIWI whose maximum charge rate is
more than 200 pounds per hour but less than or equal to 500 pounds per
hour; or
(iii) A batch HMIWI whose maximum charge rate is more than 1,600
pounds per day but less than or equal to 4,000 pounds per day.
(2) The following are not medium HMIWI:
(i) A continuous or intermittent HMIWI whose maximum charge rate is
less than or equal to 200 pounds per hour or more than 500 pounds per
hour; or
(ii) A batch HMIWI whose maximum charge rate is more than 4,000
pounds per day or less than or equal to 1,600 pounds per day.
Minimum dioxin/furan sorbent flow rate means 90 percent of the
highest 3-hour average dioxin/furan sorbent flow rate (taken, at a
minimum, once every hour) measured during the most recent performance
test demonstrating compliance with the dioxin/furan emission limit.
Minimum Hg sorbent flow rate means 90 percent of the highest 3-hour
average Hg sorbent flow rate (taken, at a minimum, once every hour)
measured during the most recent performance test demonstrating
compliance with the Hg emission limit.
Minimum hydrogen chloride (HCl) sorbent flow rate means 90 percent
of the highest 3-hour average HCl sorbent flow rate (taken, at a
minimum, once every hour) measured during the most recent performance
test demonstrating compliance with the HCl emission limit.
Minimum horsepower or amperage means 90 percent of the highest 3-
hour average horsepower or amperage to the wet scrubber (taken, at a
minimum, once every minute) measured during the most recent performance
test demonstrating compliance with the applicable emission limits.
Minimum pressure drop across the wet scrubber means 90 percent of
the highest 3-hour average pressure drop across the wet scrubber PM
control device (taken, at a minimum, once every minute) measured during
the most recent performance test demonstrating compliance with the PM
emission limit.
Minimum scrubber liquor flow rate means 90 percent of the highest 3-
hour average liquor flow rate at the inlet to the wet scrubber (taken,
at a minimum, once every minute) measured during the most recent
performance test demonstrating compliance with all applicable emission
limits.
Minimum scrubber liquor pH means 90 percent of the highest 3-hour
average liquor pH at the inlet to the wet scrubber (taken, at a minimum,
once every minute) measured during the most recent performance test
demonstrating compliance with the HCl emission limit.
[[Page 194]]
Minimum secondary chamber temperature means 90 percent of the
highest 3-hour average secondary chamber temperature (taken, at a
minimum, once every minute) measured during the most recent performance
test demonstrating compliance with the PM, CO, or dioxin/furan emission
limits.
Modification or Modified HMIWI means any change to an HMIWI unit
after the effective date of these standards such that:
(1) The cumulative costs of the modifications, over the life of the
unit, exceed 50 per centum of the original cost of the construction and
installation of the unit (not including the cost of any land purchased
in connection with such construction or installation) updated to current
costs, or
(2) The change involves a physical change in or change in the method
of operation of the unit which increases the amount of any air pollutant
emitted by the unit for which standards have been established under
section 129 or section 111.
Operating day means a 24-hour period between 12:00 midnight and the
following midnight during which any amount of hospital waste or medical/
infectious waste is combusted at any time in the HMIWI.
Operation means the period during which waste is combusted in the
incinerator excluding periods of startup or shutdown.
Particulate matter or PM means the total particulate matter emitted
from an HMIWI as measured by EPA Reference Method 5 or EPA Reference
Method 29.
Pathological waste means waste material consisting of only human or
animal remains, anatomical parts, and/or tissue, the bags/containers
used to collect and transport the waste material, and animal bedding (if
applicable).
Primary chamber means the chamber in an HMIWI that receives waste
material, in which the waste is ignited, and from which ash is removed.
Pyrolysis means the endothermic gasification of hospital waste and/
or medical/infectious waste using external energy.
Secondary chamber means a component of the HMIWI that receives
combustion gases from the primary chamber and in which the combustion
process is completed.
Shutdown means the period of time after all waste has been combusted
in the primary chamber. For continuous HMIWI, shutdown shall commence no
less than 2 hours after the last charge to the incinerator. For
intermittent HMIWI, shutdown shall commence no less than 4 hours after
the last charge to the incinerator. For batch HMIWI, shutdown shall
commence no less than 5 hours after the high-air phase of combustion has
been completed.
Small HMIWI means:
(1) Except as provided in (2);
(i) An HMIWI whose maximum design waste burning capacity is less
than or equal to 200 pounds per hour; or
(ii) A continuous or intermittent HMIWI whose maximum charge rate is
less than or equal to 200 pounds per hour; or
(iii) A batch HMIWI whose maximum charge rate is less than or equal
to 1,600 pounds per day.
(2) The following are not small HMIWI:
(i) A continuous or intermittent HMIWI whose maximum charge rate is
more than 200 pounds per hour;
(ii) A batch HMIWI whose maximum charge rate is more than 1,600
pounds per day.
Standard conditions means a temperature of 20 deg.C and a pressure
of 101.3 kilopascals.
Startup means the period of time between the activation of the
system and the first charge to the unit. For batch HMIWI, startup means
the period of time between activation of the system and ignition of the
waste.
Wet scrubber means an add-on air pollution control device that
utilizes an alkaline scrubbing liquor to collect particulate matter
(including nonvaporous metals and condensed organics) and/or to absorb
and neutralize acid gases.
Sec. 60.52c Emission limits.
(a) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, no owner or operator of an affected facility shall cause to
be discharged into
[[Page 195]]
the atmosphere from that affected facility any gases that contain stack
emissions in excess of the limits presented in Table 1 of this subpart.
(b) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, no owner or operator of an affected facility shall cause to
be discharged into the atmosphere from the stack of that affected
facility any gases that exhibit greater than 10 percent opacity (6-
minute block average).
(c) On and after the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, no owner or operator of an affected facility utilizing a
large HMIWI shall cause to be discharged into the atmosphere visible
emissions of combustion ash from an ash conveying system (including
conveyor transfer points) in excess of 5 percent of the observation
period (i.e., 9 minutes per 3-hour period), as determined by EPA
Reference Method 22, except as provided in paragraphs (d) and (e) of
this section.
(d) The emission limit specified in paragraph (c) of this section
does not cover visible emissions discharged inside buildings or
enclosures of ash conveying systems; however, the emission limit does
cover visible emissions discharged to the atmosphere from buildings or
enclosures of ash conveying systems.
(e) The provisions specified in paragraph (c) of this section do not
apply during maintenance and repair of ash conveying systems.
Maintenance and/or repair shall not exceed 10 operating days per
calendar quarter unless the owner or operator obtains written approval
from the State agency establishing a date whereby all necessary
maintenance and repairs of ash conveying systems shall be completed.
Sec. 60.53c Operator training and qualification requirements.
(a) No owner or operator of an affected facility shall allow the
affected facility to operate at any time unless a fully trained and
qualified HMIWI operator is accessible, either at the facility or
available within 1 hour. The trained and qualified HMIWI operator may
operate the HMIWI directly or be the direct supervisor of one or more
HMIWI operators.
(b) Operator training and qualification shall be obtained through a
State-approved program or by completing the requirements included in
paragraphs (c) through (g) of this section.
(c) Training shall be obtained by completing an HMIWI operator
training course that includes, at a minimum, the following provisions:
(1) 24 hours of training on the following subjects:
(i) Environmental concerns, including pathogen destruction and types
of emissions;
(ii) Basic combustion principles, including products of combustion;
(iii) Operation of the type of incinerator to be used by the
operator, including proper startup, waste charging, and shutdown
procedures;
(iv) Combustion controls and monitoring;
(v) Operation of air pollution control equipment and factors
affecting performance (if applicable);
(vi) Methods to monitor pollutants (continuous emission monitoring
systems and monitoring of HMIWI and air pollution control device
operating parameters) and equipment calibration procedures (where
applicable);
(vii) Inspection and maintenance of the HMIWI, air pollution control
devices, and continuous emission monitoring systems;
(viii) Actions to correct malfunctions or conditions that may lead
to malfunction;
(ix) Bottom and fly ash characteristics and handling procedures;
(x) Applicable Federal, State, and local regulations;
(xi) Work safety procedures;
(xii) Pre-startup inspections; and
(xiii) Recordkeeping requirements.
(2) An examination designed and administered by the instructor.
(3) Reference material distributed to the attendees covering the
course topics.
(d) Qualification shall be obtained by:
(1) Completion of a training course that satisfies the criteria
under paragraph (c) of this section; and
[[Page 196]]
(2) Either 6 months experience as an HMIWI operator, 6 months
experience as a direct supervisor of an HMIWI operator, or completion of
at least two burn cycles under the observation of two qualified HMIWI
operators.
(e) Qualification is valid from the date on which the examination is
passed or the completion of the required experience, whichever is later.
(f) To maintain qualification, the trained and qualified HMIWI
operator shall complete and pass an annual review or refresher course of
at least 4 hours covering, at a minimum, the following:
(1) Update of regulations;
(2) Incinerator operation, including startup and shutdown
procedures;
(3) Inspection and maintenance;
(4) Responses to malfunctions or conditions that may lead to
malfunction; and
(5) Discussion of operating problems encountered by attendees.
(g) A lapsed qualification shall be renewed by one of the following
methods:
(1) For a lapse of less than 3 years, the HMIWI operator shall
complete and pass a standard annual refresher course described in
paragraph (f) of this section.
(2) For a lapse of 3 years or more, the HMIWI operator shall
complete and pass a training course with the minimum criteria described
in paragraph (c) of this section.
(h) The owner or operator of an affected facility shall maintain
documentation at the facility that address the following:
(1) Summary of the applicable standards under this subpart;
(2) Description of basic combustion theory applicable to an HMIWI;
(3) Procedures for receiving, handling, and charging waste;
(4) HMIWI startup, shutdown, and malfunction procedures;
(5) Procedures for maintaining proper combustion air supply levels;
(6) Procedures for operating the HMIWI and associated air pollution
control systems within the standards established under this subpart;
(7) Procedures for responding to periodic malfunction or conditions
that may lead to malfunction;
(8) Procedures for monitoring HMIWI emissions;
(9) Reporting and recordkeeping procedures; and
(10) Procedures for handling ash.
(i) The owner or operator of an affected facility shall establish a
program for reviewing the information listed in paragraph (h) of this
section annually with each HMIWI operator (defined in Sec. 60.51c).
(1) The initial review of the information listed in paragraph (h) of
this section shall be conducted within 6 months after the effective date
of this subpart or prior to assumption of responsibilities affecting
HMIWI operation, whichever date is later.
(2) Subsequent reviews of the information listed in paragraph (h) of
this section shall be conducted annually.
(j) The information listed in paragraph (h) of this section shall be
kept in a readily accessible location for all HMIWI operators. This
information, along with records of training shall be available for
inspection by the EPA or its delegated enforcement agent upon request.
Sec. 60.54c Siting requirements.
(a) The owner or operator of an affected facility for which
construction is commenced after September 15, 1997 shall prepare an
analysis of the impacts of the affected facility. The analysis shall
consider air pollution control alternatives that minimize, on a site-
specific basis, to the maximum extent practicable, potential risks to
public health or the environment. In considering such alternatives, the
analysis may consider costs, energy impacts, non-air environmental
impacts, or any other factors related to the practicability of the
alternatives.
(b) Analyses of facility impacts prepared to comply with State,
local, or other Federal regulatory requirements may be used to satisfy
the requirements of this section, as long as they include the
consideration of air pollution control alternatives specified in
paragraph (a) of this section.
(c) The owner or operator of the affected facility shall complete
and submit the siting requirements of this section as required under
Sec. 60.58c(a)(1)(iii).
[[Page 197]]
Sec. 60.55c Waste management plan.
The owner or operator of an affected facility shall prepare a waste
management plan. The waste management plan shall identify both the
feasibility and the approach to separate certain components of solid
waste from the health care waste stream in order to reduce the amount of
toxic emissions from incinerated waste. A waste management plan may
include, but is not limited to, elements such as paper, cardboard,
plastics, glass, battery, or metal recycling; or purchasing recycled or
recyclable products. A waste management plan may include different goals
or approaches for different areas or departments of the facility and
need not include new waste management goals for every waste stream. It
should identify, where possible, reasonably available additional waste
management measures, taking into account the effectiveness of waste
management measures already in place, the costs of additional measures,
the emission reductions expected to be achieved, and any other
environmental or energy impacts they might have. The American Hospital
Association publication entitled ``An Ounce of Prevention: Waste
Reduction Strategies for Health Care Facilities'' (incorporated by
reference, see Sec. 60.17) shall be considered in the development of the
waste management plan.
Sec. 60.56c Compliance and performance testing.
(a) The emission limits under this subpart apply at all times except
during periods of startup, shutdown, or malfunction, provided that no
hospital waste or medical/infectious waste is charged to the affected
facility during startup, shutdown, or malfunction.
(b) The owner or operator of an affected facility shall conduct an
initial performance test as required under Sec. 60.8 to determine
compliance with the emission limits using the procedures and test
methods listed in paragraphs (b)(1) through (b)(12) of this section. The
use of the bypass stack during a performance test shall invalidate the
performance test.
(1) All performance tests shall consist of a minimum of three test
runs conducted under representative operating conditions.
(2) The minimum sample time shall be 1 hour per test run unless
otherwise indicated.
(3) EPA Reference Method 1 of appendix A of this part shall be used
to select the sampling location and number of traverse points.
(4) EPA Reference Method 3, 3A, or 3B of appendix A of this part
shall be used for gas composition analysis, including measurement of
oxygen concentration. EPA Reference Method 3, 3A, or 3B of appendix A of
this part shall be used simultaneously with each reference method.
(5) The pollutant concentrations shall be adjusted to 7 percent
oxygen using the following equation:
Cadj=Cmeas (20.9--7)/(20.9--%O2) where:
Cadj=pollutant concentration adjusted to 7 percent oxygen;
Cmeas=pollutant concentration measured on a dry basis (20.9--
7)=20.9 percent oxygen--7 percent oxygen (defined oxygen correction
basis);
20.9=oxygen concentration in air, percent; and
%O2=oxygen concentration measured on a dry basis, percent.
(6) EPA Reference Method 5 or 29 of appendix A of this part shall be
used to measure the particulate matter emissions.
(7) EPA Reference Method 9 of appendix A of this part shall be used
to measure stack opacity.
(8) EPA Reference Method 10 or 10B of appendix A of this part shall
be used to measure the CO emissions.
(9) EPA Reference Method 23 of appendix A of this part shall be used
to measure total dioxin/furan emissions. The minimum sample time shall
be 4 hours per test run. If the affected facility has selected the toxic
equivalency standards for dioxin/furans, under Sec. 60.52c, the
following procedures shall be used to determine compliance:
(i) Measure the concentration of each dioxin/furan tetra-through
octa-congener emitted using EPA Reference Method 23.
(ii) For each dioxin/furan congener measured in accordance with
paragraph (b)(9)(i) of this section, multiply
[[Page 198]]
the congener concentration by its corresponding toxic equivalency factor
specified in Table 2 of this subpart.
(iii) Sum the products calculated in accordance with paragraph
(b)(9)(ii) of this section to obtain the total concentration of dioxins/
furans emitted in terms of toxic equivalency.
(10) EPA Reference Method 26 or 26A of appendix A of this part shall
be used to measure HCl emissions. If the affected facility has selected
the percentage reduction standards for HCl under Sec. 60.52c, the
percentage reduction in HCl emissions (%RHCl) is computed
using the following formula:
[GRAPHIC] [TIFF OMITTED] TR15SE97.000
Where:
%RHCl=percentage reduction of HCl emissions achieved;
Ei=HCl emission concentration measured at the control device
inlet, corrected to 7 percent oxygen (dry basis); and
Eo=HCl emission concentration measured at the control device
outlet, corrected to 7 percent oxygen (dry basis).
(11) EPA Reference Method 29 of appendix A of this part shall be
used to measure Pb, Cd, and Hg emissions. If the affected facility has
selected the percentage reduction standards for metals under
Sec. 60.52c, the percentage reduction in emissions (%Rmetal)
is computed using the following formula:
[GRAPHIC] [TIFF OMITTED] TC16NO91.251
Where:
%Rmetal=percentage reduction of metal emission (Pb, Cd, or
Hg) achieved;
Ei=metal emission concentration (Pb, Cd, or Hg) measured at
the control device inlet, corrected to 7 percent oxygen (dry basis); and
Eo=metal emission concentration (Pb, Cd, or Hg) measured at
the control device outlet, corrected to 7 percent oxygen (dry basis).
(12) The EPA Reference Method 22 of appendix A of this part shall be
used to determine compliance with the fugitive ash emission limit under
Sec. 60.52c(c). The minimum observation time shall be a series of three
1-hour observations.
(c) Following the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, the owner or operator of an affected facility shall:
(1) Determine compliance with the opacity limit by conducting an
annual performance test (no more than 12 months following the previous
performance test) using the applicable procedures and test methods
listed in paragraph (b) of this section.
(2) Determine compliance with the PM, CO, and HCl emission limits by
conducting an annual performance test (no more than 12 months following
the previous performance test) using the applicable procedures and test
methods listed in paragraph (b) of this section. If all three
performance tests over a 3-year period indicate compliance with the
emission limit for a pollutant (PM, CO, or HCl), the owner or operator
may forego a performance test for that pollutant for the subsequent 2
years. At a minimum, a performance test for PM, CO, and HCl shall be
conducted every third year (no more than 36 months following the
previous performance test). If a performance test conducted every third
year indicates compliance with the emission limit for a pollutant (PM,
CO, or HCl), the owner or operator may forego a performance test for
that pollutant for an additional 2 years. If any performance test
indicates noncompliance with the respective emission limit, a
performance test for that pollutant shall be conducted annually until
all annual performance tests over a 3-year period indicate compliance
with the emission limit. The use of the bypass stack during a
performance test shall invalidate the performance test.
(3) For large HMIWI, determine compliance with the visible emission
limits for fugitive emissions from flyash/bottom ash storage and
handling by conducting a performance test using EPA Reference Method 22
on an annual basis (no more than 12 months following the previous
performance test).
(4) Facilities using a CEMS to demonstrate compliance with any of
the emission limits under Sec. 60.52c shall:
[[Page 199]]
(i) Determine compliance with the appropriate emission limit(s)
using a 12-hour rolling average, calculated each hour as the average of
the previous 12 operating hours (not including startup, shutdown, or
malfunction).
(ii) Operate all CEMS in accordance with the applicable procedures
under appendices B and F of this part.
(d) The owner or operator of an affected facility equipped with a
dry scrubber followed by a fabric filter, a wet scrubber, or a dry
scrubber followed by a fabric filter and wet scrubber shall:
(1) Establish the appropriate maximum and minimum operating
parameters, indicated in Table 3 of this subpart for each control
system, as site specific operating parameters during the initial
performance test to determine compliance with the emission limits; and
(2) Following the date on which the initial performance test is
completed or is required to be completed under Sec. 60.8, whichever date
comes first, ensure that the affected facility does not operate above
any of the applicable maximum operating parameters or below any of the
applicable minimum operating parameters listed in Table 3 of this
subpart and measured as 3-hour rolling averages (calculated each hour as
the average of the previous 3 operating hours) at all times except
during periods of startup, shutdown and malfunction. Operating parameter
limits do not apply during performance tests. Operation above the
established maximum or below the established minimum operating
parameter(s) shall constitute a violation of established operating
parameter(s).
(e) Except as provided in paragraph (h) of this section, for
affected facilities equipped with a dry scrubber followed by a fabric
filter:
(1) Operation of the affected facility above the maximum charge rate
and below the minimum secondary chamber temperature (each measured on a
3-hour rolling average) simultaneously shall constitute a violation of
the CO emission limit.
(2) Operation of the affected facility above the maximum fabric
filter inlet temperature, above the maximum charge rate, and below the
minimum dioxin/furan sorbent flow rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the
dioxin/furan emission limit.
(3) Operation of the affected facility above the maximum charge rate
and below the minimum HCl sorbent flow rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the HCl
emission limit.
(4) Operation of the affected facility above the maximum charge rate
and below the minimum Hg sorbent flow rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the Hg
emission limit.
(5) Use of the bypass stack (except during startup, shutdown, or
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl,
Pb, Cd and Hg emission limits.
(f) Except as provided in paragraph (h) of this section, for
affected facilities equipped with a wet scrubber:
(1) Operation of the affected facility above the maximum charge rate
and below the minimum pressure drop across the wet scrubber or below the
minimum horsepower or amperage to the system (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the PM
emission limit.
(2) Operation of the affected facility above the maximum charge rate
and below the minimum secondary chamber temperature (each measured on a
3-hour rolling average) simultaneously shall constitute a violation of
the CO emission limit.
(3) Operation of the affected facility above the maximum charge
rate, below the minimum secondary chamber temperature, and below the
minimum scrubber liquor flow rate (each measured on a 3-hour rolling
average) simultaneously shall constitute a violation of the dioxin/furan
emission limit.
(4) Operation of the affected facility above the maximum charge rate
and below the minimum scrubber liquor pH (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the HCl
emission limit.
[[Page 200]]
(5) Operation of the affected facility above the maximum flue gas
temperature and above the maximum charge rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the Hg
emission limit.
(6) Use of the bypass stack (except during startup, shutdown, or
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl,
Pb, Cd and Hg emission limits.
(g) Except as provided in paragraph (h) of this section, for
affected facilities equipped with a dry scrubber followed by a fabric
filter and a wet scrubber:
(1) Operation of the affected facility above the maximum charge rate
and below the minimum secondary chamber temperature (each measured on a
3-hour rolling average) simultaneously shall constitute a violation of
the CO emission limit.
(2) Operation of the affected facility above the maximum fabric
filter inlet temperature, above the maximum charge rate, and below the
minimum dioxin/furan sorbent flow rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the
dioxin/furan emission limit.
(3) Operation of the affected facility above the maximum charge rate
and below the minimum scrubber liquor pH (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the HCl
emission limit.
(4) Operation of the affected facility above the maximum charge rate
and below the minimum Hg sorbent flow rate (each measured on a 3-hour
rolling average) simultaneously shall constitute a violation of the Hg
emission limit.
(5) Use of the bypass stack (except during startup, shutdown, or
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl,
Pb, Cd and Hg emission limits.
(h) The owner or operator of an affected facility may conduct a
repeat performance test within 30 days of violation of applicable
operating parameter(s) to demonstrate that the affected facility is not
in violation of the applicable emission limit(s). Repeat performance
tests conducted pursuant to this paragraph shall be conducted using the
identical operating parameters that indicated a violation under
paragraph (e), (f), or (g) of this section.
(i) The owner or operator of an affected facility using an air
pollution control device other than a dry scrubber followed by a fabric
filter, a wet scrubber, or a dry scrubber followed by a fabric filter
and a wet scrubber to comply with the emission limits under Sec. 60.52c
shall petition the Administrator for other site-specific operating
parameters to be established during the initial performance test and
continuously monitored thereafter. The owner or operator shall not
conduct the initial performance test until after the petition has been
approved by the Administrator.
(j) The owner or operator of an affected facility may conduct a
repeat performance test at any time to establish new values for the
operating parameters. The Administrator may request a repeat performance
test at any time.
[62 FR 48382, Sept. 15, 1997, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.57c Monitoring requirements.
(a) The owner or operator of an affected facility shall install,
calibrate (to manufacturers' specifications), maintain, and operate
devices (or establish methods) for monitoring the applicable maximum and
minimum operating parameters listed in Table 3 of this subpart such that
these devices (or methods) measure and record values for these operating
parameters at the frequencies indicated in Table 3 of this subpart at
all times except during periods of startup and shutdown.
(b) The owner or operator of an affected facility shall install,
calibrate (to manufacturers' specifications), maintain, and operate a
device or method for measuring the use of the bypass stack including
date, time, and duration.
(c) The owner or operator of an affected facility using something
other than a dry scrubber followed by a fabric filter, a wet scrubber,
or a dry scrubber followed by a fabric filter and a wet scrubber to
comply with the emission limits under Sec. 60.52c shall install,
calibrate (to the manufacturers'
[[Page 201]]
specifications), maintain, and operate the equipment necessary to
monitor the site-specific operating parameters developed pursuant to
Sec. 60.56c(i).
(d) The owner or operator of an affected facility shall obtain
monitoring data at all times during HMIWI operation except during
periods of monitoring equipment malfunction, calibration, or repair. At
a minimum, valid monitoring data shall be obtained for 75 percent of the
operating hours per day and for 90 percent of the operating days per
calendar quarter that the affected facility is combusting hospital waste
and/or medical/infectious waste.
Sec. 60.58c Reporting and recordkeeping requirements.
(a) The owner or operator of an affected facility shall submit
notifications, as provided by Sec. 60.7. In addition, the owner or
operator shall submit the following information:
(1) Prior to commencement of construction;
(i) A statement of intent to construct;
(ii) The anticipated date of commencement of construction; and
(iii) All documentation produced as a result of the siting
requirements of Sec. 60.54c.
(2) Prior to initial startup;
(i) The type(s) of waste to be combusted;
(ii) The maximum design waste burning capacity;
(iii) The anticipated maximum charge rate; and
(iv) If applicable, the petition for site-specific operating
parameters under Sec. 60.56c(i).
(b) The owner or operator of an affected facility shall maintain the
following information (as applicable) for a period of at least 5 years:
(1) Calendar date of each record;
(2) Records of the following data:
(i) Concentrations of any pollutant listed in Sec. 60.52c or
measurements of opacity as determined by the continuous emission
monitoring system (if applicable);
(ii) Results of fugitive emissions (by EPA Reference Method 22)
tests, if applicable;
(iii) HMIWI charge dates, times, and weights and hourly charge
rates;
(iv) Fabric filter inlet temperatures during each minute of
operation, as applicable;
(v) Amount and type of dioxin/furan sorbent used during each hour of
operation, as applicable;
(vi) Amount and type of Hg sorbent used during each hour of
operation, as applicable;
(vii) Amount and type of HCl sorbent used during each hour of
operation, as applicable;
(viii) Secondary chamber temperatures recorded during each minute of
operation;
(ix) Liquor flow rate to the wet scrubber inlet during each minute
of operation, as applicable;
(x) Horsepower or amperage to the wet scrubber during each minute of
operation, as applicable;
(xi) Pressure drop across the wet scrubber system during each minute
of operation, as applicable,
(xii) Temperature at the outlet from the wet scrubber during each
minute of operation, as applicable;
(xiii) pH at the inlet to the wet scrubber during each minute of
operation, as applicable,
(xiv) Records indicating use of the bypass stack, including dates,
times, and durations, and
(xv) For affected facilities complying with Secs. 60.56c(i) and
60.57c(c), the owner or operator shall maintain all operating parameter
data collected.
(3) Identification of calendar days for which data on emission rates
or operating parameters specified under paragraph (b)(2) of this section
have not been obtained, with an identification of the emission rates or
operating parameters not measured, reasons for not obtaining the data,
and a description of corrective actions taken.
(4) Identification of calendar days, times and durations of
malfunctions, a description of the malfunction and the corrective action
taken.
(5) Identification of calendar days for which data on emission rates
or operating parameters specified under paragraph (b)(2) of this section
exceeded the applicable limits, with a description of the exceedances,
reasons for such exceedances, and a description of corrective actions
taken.
[[Page 202]]
(6) The results of the initial, annual, and any subsequent
performance tests conducted to determine compliance with the emission
limits and/or to establish operating parameters, as applicable.
(7) All documentation produced as a result of the siting
requirements of Sec. 60.54c;
(8) Records showing the names of HMIWI operators who have completed
review of the information in Sec. 60.53c(h) as required by
Sec. 60.53c(i), including the date of the initial review and all
subsequent annual reviews;
(9) Records showing the names of the HMIWI operators who have
completed the operator training requirements, including documentation of
training and the dates of the training;
(10) Records showing the names of the HMIWI operators who have met
the criteria for qualification under Sec. 60.53c and the dates of their
qualification; and
(11) Records of calibration of any monitoring devices as required
under Sec. 60.57c (a), (b), and (c).
(c) The owner or operator of an affected facility shall submit the
information specified in paragraphs (c)(1) through (c)(3) of this
section no later than 60 days following the initial performance test.
All reports shall be signed by the facilities manager.
(1) The initial performance test data as recorded under Sec. 60.56c
(b)(1) through (b)(12), as applicable.
(2) The values for the site-specific operating parameters
established pursuant to Sec. 60.56c (d) or (i), as applicable.
(3) The waste management plan as specified in Sec. 60.55c.
(d) An annual report shall be submitted 1 year following the
submission of the information in paragraph (c) of this section and
subsequent reports shall be submitted no more than 12 months following
the previous report (once the unit is subject to permitting requirements
under Title V of the Clean Air Act, the owner or operator of an affected
facility must submit these reports semiannually). The annual report
shall include the information specified in paragraphs (d)(1) through
(d)(8) of this section. All reports shall be signed by the facilities
manager.
(1) The values for the site-specific operating parameters
established pursuant to Sec. 60.56c (d) or (i), as applicable.
(2) The highest maximum operating parameter and the lowest minimum
operating parameter, as applicable, for each operating parameter
recorded for the calendar year being reported, pursuant to
Sec. 60.56c(d) or (i), as applicable.
(3) The highest maximum operating parameter and the lowest minimum
operating parameter, as applicable for each operating parameter recorded
pursuant to Sec. 60.56c (d) or (i) for the calendar year preceding the
year being reported, in order to provide the Administrator with a
summary of the performance of the affected facility over a 2-year
period.
(4) Any information recorded under paragraphs (b)(3) through (b)(5)
of this section for the calendar year being reported.
(5) Any information recorded under paragraphs (b)(3) through (b)(5)
of this section for the calendar year preceding the year being reported,
in order to provide the Administrator with a summary of the performance
of the affected facility over a 2-year period.
(6) If a performance test was conducted during the reporting period,
the results of that test.
(7) If no exceedances or malfunctions were reported under paragraphs
(b)(3) through (b)(5) of this section for the calendar year being
reported, a statement that no exceedances occurred during the reporting
period.
(8) Any use of the bypass stack, the duration, reason for
malfunction, and corrective action taken.
(e) The owner or operator of an affected facility shall submit
semiannual reports containing any information recorded under paragraphs
(b)(3) through (b)(5) of this section no later than 60 days following
the reporting period. The first semiannual reporting period ends 6
months following the submission of information in paragraph (c) of this
section. Subsequent reports shall be submitted no later than 6 calendar
months following the previous report. All reports shall be signed by the
facilities manager.
(f) All records specified under paragraph (b) of this section shall
be maintained onsite in either paper copy or
[[Page 203]]
computer-readable format, unless an alternative format is approved by
the Administrator.
Table 1 to Subpart Ec--Emission Limits for Small, Medium, and Large HMIWI
----------------------------------------------------------------------------------------------------------------
Emission limits
--------------------------------------------------------
Pollutant Units (7 percent HMIWI size
oxygen, dry basis) --------------------------------------------------------
Small Medium Large
----------------------------------------------------------------------------------------------------------------
Particulate matter............. Milligrams per dry 69 (0.03)........ 34 (0.015)....... 34 (0.015).
standard cubic meter
(grains per dry
standard cubic foot).
Carbon monoxide................ Parts per million by 40............... 40............... 40.
volume.
Dioxins/furans................. Nanograms per dry 125 (55) or 2.3 25 (11) or 0.6 25 (11) or 0.6
standard cubic meter (1.0). (0.26). (0.26).
total dioxins/furans
(grains per billion
dry standard cubic
feet) or nanograms
per dry standard
cubic meter total
dioxins/furans TEQ
(grains per billion
dry standard cubic
feet).
Hydrogen chloride.............. Parts per million or 15 or 99%........ 15 or 99%........ 15 or 99%.
percent reduction.
Sulfur dioxide................. Parts per million by 55............... 55............... 55.
volume.
Nitrogen oxides................ Parts per million by 250.............. 250.............. 250.
volume.
Lead........................... Milligrams per dry 1.2 (0.52) or 70% 0.07 (0.03) or 0.07 (0.03) or
standard cubic meter 98%. 98%.
(grains per thousand
dry standard cubic
feet) or percent
reduction.
Cadmium........................ Milligrams per dry 0.16 (0.07) or 0.04 (0.02) or 0.04 (0.02) or
standard cubic meter 65%. 90%. 90%.
(grains per thousand
dry standard cubic
feet) or percent
reduction.
Mercury........................ Milligrams per dry 0.55 (0.24) or 0.55 (0.24) or 0.55 (0.24) or
standard cubic meter 85%. 85%. 85%.
(grains per thousand
dry standard cubic
feet) or percent
reduction.
----------------------------------------------------------------------------------------------------------------
Table 2 To Supbart Ec--Toxic Equivalency Factors
------------------------------------------------------------------------
Toxic
Dioxin/furan congener equivalency
factor
------------------------------------------------------------------------
2,3,7,8-tetrachlorinated dibenzo-p-dioxin................. 1
1,2,3,7,8-pentachlorinated dibenzo-p-dioxin............... 0.5
1,2,3,4,7,8-hexachlorinated dibenzo-p-dioxin.............. 0.1
1,2,3,7,8,9-hexachlorinated dibenzo-p-dioxin.............. 0.1
1,2,3,6,7,8-hexachlorinated dibenzo-p-dioxin.............. 0.1
1,2,3,4,6,7,8-heptachlorinated dibenzo-p-dioxin........... 0.01
octachlorinated dibenzo-p-dioxin.......................... 0.001
2,3,7,8-tetrachlorinated dibenzofuran..................... 0.1
2,3,4,7,8-pentachlorinated dibenzofuran................... 0.5
1,2,3,7,8-pentachlorinated dibenzofuran................... 0.05
1,2,3,4,7,8-hexachlorinated dibenzofuran.................. 0.1
1,2,3,6,7,8-hexachlorinated dibenzofuran.................. 0.1
1,2,3,7,8,9-hexachlorinated dibenzofuran.................. 0.1
2,3,4,6,7,8-hexachlorinated dibenzofuran.................. 0.1
1,2,3,4,6,7,8-heptachlorinated dibenzofuran............... 0.01
1,2,3,4,7,8,9-heptachlorinated dibenzofuran............... 0.01
Octachlorinated dibenzofuran.............................. 0.001
------------------------------------------------------------------------
Table 3 to Subpart Ec--Operating Parameters to be Monitored and Minimum Measurement and Recording Frequencies
--------------------------------------------------------------------------------------------------------------------------------------------------------
Minimum frequency Control system
--------------------------------------------------------------------------------------------------------------
Dry scrubber
Operating parameters to be monitored Dry scrubber followed by
Data measurement Data recording followed by Wet scrubber fabric
fabric filter and
filter wet scrubber
--------------------------------------------------------------------------------------------------------------------------------------------------------
Maximum operating parameters:
Maximum charge rate.................. Continuous....................... 1 x hour........................
Maximum fabric filter inlet Continuous....................... 1 x minute...................... ............
temperature.
Maximum flue gas temperature......... Continuous....................... 1 x minute......................
[[Page 204]]
Minimum operating parameters:
Minimum secondary chamber temperature Continuous....................... 1 x minute......................
Minimum dioxin/furan sorbent flow Hourly........................... 1 x hour........................ ............
rate.
Minimum HCI sorbent flow rate........ Hourly........................... 1 x hour........................ ............
Minimum mercury (Hg) sorbent flow Hourly........................... 1 x hour........................ ............
rate.
Minimum pressure drop across the wet Continuous....................... 1 x minute...................... ............
scrubber or minimum horsepower or
amperage to wet scrubber.
Minimum scrubber liquor flow rate.... Continuous....................... 1 x minute...................... ............
Minimum scrubber liquor pH........... Continuous....................... 1 x minute...................... ............
--------------------------------------------------------------------------------------------------------------------------------------------------------
Subpart F--Standards of Performance for Portland Cement Plants
Sec. 60.60 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to the following
affected facilities in portland cement plants: Kiln, clinker cooler, raw
mill system, finish mill system, raw mill dryer, raw material storage,
clinker storage, finished product storage, conveyor transfer points,
bagging and bulk loading and unloading systems.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after August 17, 1971, is subject to the
requirements of this subpart.
[42 FR 37936, July 25, 1977]
Sec. 60.61 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Portland cement plant means any facility manufacturing portland
cement by either the wet or dry process.
(b) Bypass means any system that prevents all or a portion of the
kiln or clinker cooler exhaust gases from entering the main control
device and ducts the gases through a separate control device. This does
not include emergency systems designed to duct exhaust gases directly to
the atmosphere in the event of a malfunction of any control device
controlling kiln or clinker cooler emissions.
(c) Bypass stack means the stack that vents exhaust gases to the
atmosphere from the bypass control device.
(d) Monovent means an exhaust configuration of a building or
emission control device (e.g., positive-pressure fabric filter) that
extends the length of the structure and has a width very small in
relation to its length (i.e., length to width ratio is typically greater
than 5:1). The exhaust may be an open vent with or without a roof,
louvered vents, or a combination of such features.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20793, June 13, 1974;
53 FR 50363, Dec. 14, 1988]
Sec. 60.62 Standard for particulate matter.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any kiln any gases which:
(1) Contain particulate matter in excess of 0.15 kg per metric ton
of feed (dry basis) to the kiln (0.30 lb per ton).
[[Page 205]]
(2) Exhibit greater than 20 percent opacity.
(b) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any clinker cooler any gases which:
(1) Contain particulate matter in excess of 0.050 kg per metric ton
of feed (dry basis) to the kiln (0.10 lb per ton).
(2) Exhibit 10 percent opacity, or greater.
(c) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility other than the kiln and clinker
cooler any gases which exhibit 10 percent opacity, or greater.
[39 FR 20793, June 14, 1974, as amended at 39 FR 39874, Nov. 12, 1974;
40 FR 46258, Oct. 6, 1975]
Sec. 60.63 Monitoring of operations.
(a) The owner or operator of any portland cement plant subject to
the provisions of this part shall record the daily production rates and
kiln feed rates.
(b) Except as provided in paragraph (c) of this section, each owner
or operator of a kiln or clinker cooler that is subject to the
provisions of this subpart shall install, calibrate, maintain, and
operate in accordance with Sec. 60.13 a continuous opacity monitoring
system to measure the opacity of emissions discharged into the
atmosphere from any kiln or clinker cooler. Except as provided in
paragraph (c) of this section, a continuous opacity monitoring system
shall be installed on each stack of any multiple stack device
controlling emissions from any kiln or clinker cooler. If there is a
separate bypass installed, each owner or operator of a kiln or clinker
cooler shall also install, calibrate, maintain, and operate a continuous
opacity monitoring system on each bypass stack in addition to the main
control device stack. Each owner or operator of an affected kiln or
clinker cooler for which the performance test required under Sec. 60.8
has been completed on or prior to December 14, 1988, shall install the
continuous opacity monitoring system within 180 days after December 14,
1988.
(c) Each owner or operator of a kiln or clinker cooler subject to
the provisions of this subpart using a positive-pressure fabric filter
with multiple stacks, or a negative-pressure fabric filter with multiple
stacks, or an electrostatic precipitator with multiple stacks may, in
lieu of installing the continuous opacity monitoring system required by
Sec. 60.63(b), monitor visible emissions at least once per day by using
a certified visible emissions observer. If the control device exhausts
gases through a monovent, visible emission observations in lieu of a
continuous opacity monitoring system are required. These observations
shall be taken in accordance with EPA Method 9. Visible emissions shall
be observed during conditions representative of normal operation.
Observations shall be recorded for at least three 6-minute periods each
day. In the event that visible emissions are observed for a number of
emission sites from the control device with multiple stacks, Method 9
observations shall be recorded for the emission site with the highest
opacity. All records of visible emissions shall be maintained for a
period of 2 years.
(d) For the purpose of reports under Sec. 60.65, periods of excess
emissions that shall be reported are defined as all 6-minute periods
during which the average opacity exceeds that allowed by
Sec. 60.62(a)(2) or Sec. 60.62(b)(2).
(e) The provisions of paragraphs (a), (b), and (c) of this section
apply to kilns and clinker coolers for which construction, modification,
or reconstruction commenced after August 17, 1971.
[36 FR 24877, Dec. 23, 1971, as amended at 53 FR 50363, Dec. 14, 1988]
Sec. 60.64 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
(b) The owner or operator shall determine compliance with the
particulate matter standard in Sec. 60.62 as follows:
[[Page 206]]
(1) The emission rate (E) of particulate matter shall be computed
for each run using the following equation:
E=(cs Qsd)/(P K)
where:
E=emission rate of particulate matter, kg/metric ton (lb/ton) of kiln
feed.
cs=concentration of particulate matter, g/dscm (gr/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=total kiln feed (dry basis) rate, metric ton/hr (ton/hr).
K=conversion factor, 1000 g/kg (7000 gr/lb).
(2) Method 5 shall be used to determine the particulate matter
concentration (cs) and the volumetric flow rate
(Qsd) of the effluent gas.
The sampling time and sample volume for each run shall be at least 60
minutes and 0.85 dscm (30.0 dscf) for the kiln and at least 60 minutes
and 1.15 dscm (40.6 dscf) for the clinker cooler.
(3) Suitable methods shall be used to determine the kiln feed rate
(P), except fuels, for each run. Material balance over the production
system shall be used to confirm the feed rate.
(4) Method 9 and the procedures in Sec. 60.11 shall be used to
determine opacity.
[54 FR 6666, Feb. 14, 1989, as amended at 65 FR 61753, Oct. 17, 2000]
Sec. 60.65 Recordkeeping and reporting requirements.
(a) Each owner or operator required to install a continuous opacity
monitoring system under Sec. 60.63(b) shall submit reports of excess
emissions as defined in Sec. 60.63(d). The content of these reports must
comply with the requirements in Sec. 60.7(c). Notwithstanding the
provisions of Sec. 60.7(c), such reports shall be submitted
semiannually.
(b) Each owner or operator monitoring visible emissions under
Sec. 60.63(c) shall submit semiannual reports of observed excess
emissions as defined in Sec. 60.63(d).
(c) Each owner or operator of facilities subject to the provisions
of Sec. 60.63(c) shall submit semiannual reports of the malfunction
information required to be recorded by Sec. 60.7(b). These reports shall
include the frequency, duration, and cause of any incident resulting in
deenergization of any device controlling kiln emissions or in the
venting of emissions directly to the atmosphere.
(d) The requirements of this section remain in force until and
unless the Agency, in delegating enforcement authority to a State under
section 111(c) of the Clean Air Act, 42 U.S.C. 7411, approves reporting
requirements or an alternative means of compliance surveillance adopted
by such States. In that event, affected sources within the State will be
relieved of the obligation to comply with this section, provided that
they comply with the requirements established by the State.
[53 FR 50364, Dec. 14, 1988]
Sec. 60.66 Delegation of authority.
(a) In delegating implementation and enforcement authority to a
State under section 111(c) of the Act, the authorities contained in
paragraph (b) of this section shall be retained by the Administrator and
not transferred to a State.
(b) Authorities which will not be delegated to States: No
restrictions.
[53 FR 50364, Dec. 14, 1988]
Subpart G--Standards of Performance for Nitric Acid Plants
Sec. 60.70 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to each nitric
acid production unit, which is the affected facility.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after August 17, 1971, is subject to the
requirements of this subpart.
[42 FR 37936, July 25, 1977]
Sec. 60.71 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Nitric acid production unit means any facility producing weak
nitric acid by either the pressure or atmospheric pressure process.
(b) Weak nitric acid means acid which is 30 to 70 percent in
strength.
[[Page 207]]
Sec. 60.72 Standard for nitrogen oxides.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which:
(1) Contain nitrogen oxides, expressed as NO2, in excess
of 1.5 kg per metric ton of acid produced (3.0 lb per ton), the
production being expressed as 100 percent nitric acid.
(2) Exhibit 10 percent opacity, or greater.
[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975]
Sec. 60.73 Emission monitoring.
(a) The source owner or operator shall install, calibrate, maintain,
and operate a continuous monitoring system for measuring nitrogen oxides
(NOx). The pollutant gas mixtures under Performance
Specification 2 and for calibration checks under Sec. 60.13(d) of this
part shall be nitrogen dioxide (NO2). The span value shall be
500 ppm of NO2. Method 7 shall be used for the performance
evaluations under Sec. 60.13(c). Acceptable alternative methods to
Method 7 are given in Sec. 60.74(c).
(b) The owner or operator shall establish a conversion factor for
the purpose of converting monitoring data into units of the applicable
standard (kg/metric ton, lb/ton). The conversion factor shall be
established by measuring emissions with the continuous monitoring system
concurrent with measuring emissions with the applicable reference method
tests. Using only that portion of the continuous monitoring emission
data that represents emission measurements concurrent with the reference
method test periods, the conversion factor shall be determined by
dividing the reference method test data averages by the monitoring data
averages to obtain a ratio expressed in units of the applicable standard
to units of the monitoring data, i.e., kg/metric ton per ppm (lb/ton per
ppm). The conversion factor shall be reestablished during any
performance test under Sec. 60.8 or any continuous monitoring system
performance evaluation under Sec. 60.13(c).
(c) The owner or operator shall record the daily production rate and
hours of operation.
(d) [Reserved]
(e) For the purpose of reports required under Sec. 60.7(c), periods
of excess emissions that shall be reported are defined as any 3-hour
period during which the average nitrogen oxides emissions (arithmetic
average of three contiguous 1-hour periods) as measured by a continuous
monitoring system exceed the standard under Sec. 60.72(a).
[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975; 50
FR 15894, Apr. 22, 1985; 54 FR 6666, Feb. 14, 1989]
Sec. 60.74 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
Acceptable alternative methods and procedures are given in paragraph (c)
of this section.
(b) The owner or operator shall determine compliance with the
NOx standard in Sec. 60.72 as follows:
(1) The emission rate (E) of NOx shall be computed for
each run using the following equation:
E=(Cs Qsd)/(P K)
where:
E=emission rate of NOx as NO2, kg/metric ton (lb/
ton) of 100 percent nitric acid.
Cs=concentration of NOx as NO2, g/dscm
(lb/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=acid production rate, metric ton/hr (ton/hr) or 100 percent nitric
acid.
K=conversion factor, 1000 g/kg (1.0 lb/lb).
(2) Method 7 shall be used to determine the NOx
concentration of each grab sample. Method 1 shall be used to select the
sampling site, and the sampling point shall be the centroid of the stack
or duct or at a point no closer to the walls than 1 m (3.28 ft). Four
grab samples shall be taken at approximately 15-minute intervals. The
arithmetic mean of the four sample concentrations shall constitute the
run value (Cs).
(3) Method 2 shall be used to determine the volumetric flow rate
(Qsd) of
[[Page 208]]
the effluent gas. The measurement site shall be the same as for the
NOx sample. A velocity traverse shall be made once per run
within the hour that the NOx samples are taken.
(4) The methods of Sec. 60.73(c) shall be used to determine the
production rate (P) of 100 percent nitric acid for each run. Material
balance over the production system shall be used to confirm the
production rate.
(c) The owner or operator may use the following as alternatives to
the reference methods and procedures specified in this section:
(1) For Method 7, Method 7A, 7B, 7C, or 7D may be used. If Method 7C
or 7D is used, the sampling time shall be at least 1 hour.
(d) The owner or operator shall use the procedure in Sec. 60.73(b)
to determine the conversion factor for converting the monitoring data to
the units of the standard.
[54 FR 6666, Feb. 14, 1989]
Subpart H--Standards of Performance for Sulfuric Acid Plants
Sec. 60.80 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to each sulfuric
acid production unit, which is the affected facility.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after August 17, 1971, is subject to the
requirements of this subpart.
[42 FR 37936, July 25, 1977]
Sec. 60.81 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Sulfuric acid production unit means any facility producing
sulfuric acid by the contact process by burning elemental sulfur,
alkylation acid, hydrogen sulfide, organic sulfides and mercaptans, or
acid sludge, but does not include facilities where conversion to
sulfuric acid is utilized primarily as a means of preventing emissions
to the atmosphere of sulfur dioxide or other sulfur compounds.
(b) Acid mist means sulfuric acid mist, as measured by Method 8 of
appendix A to this part or an equivalent or alternative method.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20794, June 14, 1974]
Sec. 60.82 Standard for sulfur dioxide.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which contain sulfur
dioxide in excess of 2 kg per metric ton of acid produced (4 lb per
ton), the production being expressed as 100 percent
H2SO4.
[39 FR 20794, June 14, 1974]
Sec. 60.83 Standard for acid mist.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall cause to be discharged into the
atmosphere from any affected facility any gases which:
(1) Contain acid mist, expressed as H2SO4, in
excess of 0.075 kg per metric ton of acid produced (0.15 lb per ton),
the production being expressed as 100 percent
H2SO4.
(2) Exhibit 10 percent opacity, or greater.
[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975]
Sec. 60.84 Emission monitoring.
(a) A continuous monitoring system for the measurement of sulfur
dioxide shall be installed, calibrated, maintained, and operated by the
owner or operator. The pollutant gas used to prepare calibration gas
mixtures under Performance Specification 2 and for calibration checks
under Sec. 60.13(d), shall be sulfur dioxide (SO2). Method 8
shall be used for conducting monitoring system performance evaluations
under Sec. 60.13(c) except that only the sulfur dioxide portion of the
Method 8 results shall be used. The span value shall be set at 1000 ppm
of sulfur dioxide.
(b) The owner or operator shall establish a conversion factor for
the purpose
[[Page 209]]
of converting monitoring data into units of the applicable standard (kg/
metric ton, lb/ton). The conversion factor shall be determined, as a
minimum, three times daily by measuring the concentration of sulfur
dioxide entering the converter using suitable methods (e.g., the Reich
test, National Air Pollution Control Administration Publication No. 999-
AP-13) and calculating the appropriate conversion factor for each eight-
hour period as follows:
CF=k[(1.000-0.015r)/(r-s)]
where:
CF=conversion factor (kg/metric ton per ppm, lb/ton per ppm).
k=constant derived from material balance. For determining CF in metric
units, k=0.0653. For determining CF in English units,
k=0.1306.
r=percentage of sulfur dioxide by volume entering the gas converter.
Appropriate corrections must be made for air injection plants
subject to the Administrator's approval.
s=percentage of sulfur dioxide by volume in the emissions to the
atmosphere determined by the continuous monitoring system
required under paragraph (a) of this section.
(c) The owner or operator shall record all conversion factors and
values under paragraph (b) of this section from which they were computed
(i.e., CF, r, and s).
(d) Alternatively, a source that processes elemental sulfur or an
ore that contains elemental sulfur and uses air to supply oxygen may use
the following continuous emission monitoring approach and calculation
procedures in determining SO2 emission rates in terms of the
standard. This procedure is not required, but is an alternative that
would alleviate problems encountered in the measurement of gas
velocities or production rate. Continuous emission monitoring systems
for measuring SO2, O2, and CO2 (if
required) shall be installed, calibrated, maintained, and operated by
the owner or operator and subjected to the certification procedures in
Performance Specifications 2 and 3. The calibration procedure and span
value for the SO2 monitor shall be as specified in paragraph
(b) of this section. The span value for CO2 (if required)
shall be 10 percent and for O2 shall be 20.9 percent (air). A
conversion factor based on process rate data is not necessary. Calculate
the SO2 emission rate as follows:
Es=(Cs S)/[0.265-(0.126 %O2)-(A
%CO2)]
where:
Es=emission rate of SO2, kg/metric ton (lb/ton) of
100 percent of H2SO4 produced.
Cs=concentration of SO2, kg/dscm (lb/dscf).
S=acid production rate factor, 368 dscm/metric ton (11,800 dscf/ton) of
100 percent H2SO4 produced.
%O2=oxygen concentration, percent dry basis.
A=auxiliary fuel factor,
=0.00 for no fuel.
=0.0226 for methane.
=0.0217 for natural gas.
=0.0196 for propane.
=0.0172 for No 2 oil.
=0.0161 for No 6 oil.
=0.0148 for coal.
=0.0126 for coke.
%CO2= carbon dioxide concentration, percent dry basis.
Note: It is necessary in some cases to convert measured
concentration units to other units for these calculations:
Use the following table for such conversions:
------------------------------------------------------------------------
From-- To-- Multiply by--
------------------------------------------------------------------------
g/scm............................. kg/scm.............. 10-3
mg/scm............................ kg/scm.............. 10-6
ppm (SO2)......................... kg/scm.............. 2.660 x 10-6
ppm (SO2)......................... lb/scf.............. 1.660 x 10-7
------------------------------------------------------------------------
(e) For the purpose of reports under Sec. 60.7(c), periods of excess
emissions shall be all three-hour periods (or the arithmetic average of
three consecutive one-hour periods) during which the integrated average
sulfur dioxide emissions exceed the applicable standards under
Sec. 60.82.
[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975; 48
FR 23611, May 25, 1983; 48 FR 4700, Sept. 29, 1983; 48 FR 48669, Oct.
20, 1983; 54 FR 6666, Feb. 14, 1989; 65 FR 61753, Oct. 17, 2000]
Sec. 60.85 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
Acceptable alternative methods and procedures are given in paragraph (c)
of this section.
(b) The owner or operator shall determine compliance with the
SO2 acid
[[Page 210]]
mist, and visible emission standards in Secs. 60.82 and 60.83 as
follows:
(1) The emission rate (E) of acid mist or SO2 shall be
computed for each run using the following equation:
E=(CQsd)/(PK)
where:
E=emission rate of acid mist or SO2 kg/metric ton (lb/ton) of
100 percent H2SO4 produced.
C=concentration of acid mist or SO2, g/dscm (lb/dscf).
Qsd=volumetric flow rate of the effluent gas, dscm/hr (dscf/
hr).
P=production rate of 100 percent H2SO4, metric
ton/hr (ton/hr).
K=conversion factor, 1000 g/kg (1.0 lb/lb).
(2) Method 8 shall be used to determine the acid mist and
SO2 concentrations (C's) and the volumetric flow rate
(Qsd) of the effluent gas. The moisture content may be
considered to be zero. The sampling time and sample volume for each run
shall be at least 60 minutes and 1.15 dscm (40.6 dscf).
(3) Suitable methods shall be used to determine the production rate
(P) of 100 percent H2SO4 for each run. Material
balance over the production system shall be used to confirm the
production rate.
(4) Method 9 and the procedures in Sec. 60.11 shall be used to
determine opacity.
(c) The owner or operator may use the following as alternatives to
the reference methods and procedures specified in this section:
(1) If a source processes elemental sulfur or an ore that contains
elemental sulfur and uses air to supply oxygen, the following procedure
may be used instead of determining the volumetric flow rate and
production rate:
(i) The integrated technique of Method 3 is used to determine the
O2 concentration and, if required, CO2
concentration.
(ii) The SO2 or acid mist emission rate is calculated as
described in Sec. 60.84(d), substituting the acid mist concentration for
Cs as appropriate.
[54 FR 6666, Feb. 14, 1989]
Subpart I--Standards of Performance for Hot Mix Asphalt Facilities
Sec. 60.90 Applicability and designation of affected facility.
(a) The affected facility to which the provisions of this subpart
apply is each hot mix asphalt facility. For the purpose of this subpart,
a hot mix asphalt facility is comprised only of any combination of the
following: dryers; systems for screening, handling, storing, and
weighing hot aggregate; systems for loading, transferring, and storing
mineral filler, systems for mixing hot mix asphalt; and the loading,
transfer, and storage systems associated with emission control systems.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after June 11, 1973, is subject to the
requirements of this subpart.
[42 FR 37936, July 25, 1977, as amended at 51 FR 12325, Apr. 10, 1986]
Sec. 60.91 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Hot mix asphalt facility means any facility, as described in
Sec. 60.90, used to manufacture hot mix asphalt by heating and drying
aggregate and mixing with asphalt cements.
[51 FR 12325, Apr. 10, 1986]
Sec. 60.92 Standard for particulate matter.
(a) On and after the date on which the performance test required to
be conducted by Sec. 60.8 is completed, no owner or operator subject to
the provisions of this subpart shall discharge or cause the discharge
into the atmosphere from any affected facility any gases which:
(1) Contain particulate matter in excess of 90 mg/dscm (0.04 gr/
dscf).
(2) Exhibit 20 percent opacity, or greater.
[39 FR 9314, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975]
[[Page 211]]
Sec. 60.93 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
(b) The owner or operator shall determine compliance with the
particulate matter standards in Sec. 60.92 as follows:
(1) Method 5 shall be used to determine the particulate matter
concentration. The sampling time and sample volume for each run shall be
at least 60 minutes and 0.90 dscm (31.8 dscf).
(2) Method 9 and the procedures in Sec. 60.11 shall be used to
determine opacity.
[54 FR 6667, Feb. 14, 1989]
Subpart J--Standards of Performance for Petroleum Refineries
Sec. 60.100 Applicability, designation of affected facility, and reconstruction.
(a) The provisions of this subpart are applicable to the following
affected facilities in petroleum refineries: fluid catalytic cracking
unit catalyst regenerators, fuel gas combustion devices, and all Claus
sulfur recovery plants except Claus plants of 20 long tons per day (LTD)
or less. The Claus sulfur recovery plant need not be physically located
within the boundaries of a petroleum refinery to be an affected
facility, provided it processes gases produced within a petroleum
refinery.
(b) Any fluid catalytic cracking unit catalyst regenerator or fuel
gas combustion device under paragraph (a) of this section which
commences construction or modification after June 11, 1973, or any Claus
sulfur recovery plant under paragraph (a) of this section which
commences construction or modification after October 4, 1976, is subject
to the requirements of this subpart except as provided under paragraphs
(c) and (d) of this section.
(c) Any fluid catalytic cracking unit catalyst regenerator under
paragraph (b) of this section which commences construction or
modification on or before January 17, 1984, is exempted from
Sec. 60.104(b).
(d) Any fluid catalytic cracking unit in which a contact material
reacts with petroleum derivatives to improve feedstock quality and in
which the contact material is regenerated by burning off coke and/or
other deposits and that commences construction or modification on or
before January 17, 1984, is exempt from this subpart.
(e) For purposes of this subpart, under Sec. 60.15, the ``fixed
capital cost of the new components'' includes the fixed capital cost of
all depreciable components which are or will be replaced pursuant to all
continuous programs of component replacement which are commenced within
any 2-year period following January 17, 1984. For purposes of this
paragraph, ``commenced'' means that an owner or operator has undertaken
a continuous program of component replacement or that an owner or
operator has entered into a contractual obligation to undertake and
complete, within a reasonable time, a continuous program of component
replacement.
[43 FR 10868, Mar. 15, 1978, as amended at 44 FR 61543, Oct. 25, 1979;
54 FR 34026, Aug. 17, 1989]
Sec. 60.101 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A.
(a) Petroleum refinery means any facility engaged in producing
gasoline, kerosene, distillate fuel oils, residual fuel oils,
lubricants, or other products through distillation of petroleum or
through redistillation, cracking or reforming of unfinished petroleum
derivatives.
(b) Petroleum means the crude oil removed from the earth and the
oils derived from tar sands, shale, and coal.
(c) Process gas means any gas generated by a petroleum refinery
process unit, except fuel gas and process upset gas as defined in this
section.
(d) Fuel gas means any gas which is generated at a petroleum
refinery and which is combusted. Fuel gas also includes natural gas when
the natural gas is combined and combusted in any proportion with a gas
generated at a refinery. Fuel gas does not include gases generated by
catalytic cracking
[[Page 212]]
unit catalyst regenerators and fluid coking burners.
(e) Process upset gas means any gas generated by a petroleum
refinery process unit as a result of start-up, shut-down, upset or
malfunction.
(f) Refinery process unit means any segment of the petroleum
refinery in which a specific processing operation is conducted.
(g) Fuel gas combustion device means any equipment, such as process
heaters, boilers and flares used to combust fuel gas, except facilities
in which gases are combusted to produce sulfur or sulfuric acid.
(h) Coke burn-off means the coke removed from the surface of the
fluid catalytic cracking unit catalyst by combustion in the catalyst
regenerator. The rate of coke burn-off is calculated by the formula
specified in Sec. 60.106.
(i) Claus sulfur recovery plant means a process unit which recovers
sulfur from hydrogen sulfide by a vapor-phase catalytic reaction of
sulfur dioxide and hydrogen sulfide.
(j) Oxidation control system means an emission control system which
reduces emissions from sulfur recovery plants by converting these
emissions to sulfur dioxide.
(k) Reduction control system means an emission control system which
reduces emissions from sulfur recovery plants by converting these
emissions to hydrogen sulfide.
(l) Reduced sulfur compounds means hydrogen sulfide
(H2S), carbonyl sulfide (COS) and carbon disulfide
(CS2).
(m) Fluid catalytic cracking unit means a refinery process unit in
which petroleum derivatives are continuously charged; hydrocarbon
molecules in the presence of a catalyst suspended in a fluidized bed are
fractured into smaller molecules, or react with a contact material
suspended in a fluidized bed to improve feedstock quality for additional
processing; and the catalyst or contact material is continuously
regenerated by burning off coke and other deposits. The unit includes
the riser, reactor, regenerator, air blowers, spent catalyst or contact
material stripper, catalyst or contact material recovery equipment, and
regenerator equipment for controlling air pollutant emissions and for
heat recovery.
(n) Fluid catalytic cracking unit catalyst regenerator means one or
more regenerators (multiple regenerators) which comprise that portion of
the fluid catalytic cracking unit in which coke burn-off and catalyst or
contact material regeneration occurs, and includes the regenerator
combustion air blower(s).
(o) Fresh feed means any petroleum derivative feedstock stream
charged directly into the riser or reactor of a fluid catalytic cracking
unit except for petroleum derivatives recycled within the fluid
catalytic cracking unit, fractionator, or gas recovery unit.
(p) Contact material means any substance formulated to remove
metals, sulfur, nitrogen, or any other contaminant from petroleum
derivatives.
(q) Valid day means a 24-hour period in which at least 18 valid
hours of data are obtained. A ``valid hour'' is one in which at least 2
valid data points are obtained.
[39 FR 9315, Mar. 8, 1974, as amended at 43 FR 10868, Mar. 15, 1978; 44
FR 13481, Mar. 12, 1979; 45 FR 79453, Dec. 1, 1980; 54 FR 34027, Aug.
17, 1989]
Sec. 60.102 Standard for particulate matter.
Each owner or operator of any fluid catalytic cracking unit catalyst
regenerator that is subject to the requirements of this subpart shall
comply with the emission limitations set forth in this section on and
after the date on which the initial performance test, required by
Sec. 60.8, is completed, but not later than 60 days after achieving the
maximum production rate at which the fluid catalytic cracking unit
catalyst regenerator will be operated, or 180 days after initial
startup, whichever comes first.
(a) No owner or operator subject to the provisions of this subpart
shall discharge or cause the discharge into the atmosphere from any
fluid catalytic cracking unit catalyst regenerator:
(1) Particulate matter in excess of 1.0 kg/Mg (2.0 lb/ton) of coke
burn-off in the catalyst regenerator.
(2) Gases exhibiting greater than 30 percent opacity, except for one
six-
[[Page 213]]
minute average opacity reading in any one hour period.
(b) Where the gases discharged by the fluid catalytic cracking unit
catalyst regenerator pass through an incinerator or waste heat boiler in
which auxiliary or supplemental liquid or solid fossil fuel is burned,
particulate matter in excess of that permitted by paragraph (a)(1) of
this section may be emitted to the atmosphere, except that the
incremental rate of particulate matter emissions shall not exceed 43.0
g/MJ (0.10 lb/million Btu) of heat input attributable to such liquid or
solid fossil fuel.
[39 FR 9315, Mar. 8, 1974, as amended at 42 FR 32427, June 24, 1977; 42
FR 39389, Aug. 4, 1977; 43 FR 10868, Feb. 15, 1978; 54 FR 34027, Aug.
17, 1989; 65 FR 61753, Oct. 17, 2000]
Sec. 60.103 Standard for carbon monoxide.
Each owner or operator of any fluid catalytic cracking unit catalyst
regenerator that is subject to the requirements of this subpart shall
comply with the emission limitations set forth in this section on and
after the date on which the initial performance test, required by
Sec. 60.8, is completed, but not later than 60 days after achieving the
maximum production rate at which the fluid catalytic cracking unit
catalyst regenerator will be operated, or 180 days after initial
startup, whichever comes first.
(a) No owner or operator subject to the provisions of this subpart
shall discharge or cause the discharge into the atmosphere from any
fluid catalytic cracking unit catalyst regenerator any gases that
contain carbon monoxide (CO) in excess of 500 ppm by volume (dry basis).
[54 FR 34027, Aug. 17, 1989, as amended at 55 FR 40175, Oct. 2, 1990]
Sec. 60.104 Standards for sulfur oxides.
Each owner or operator that is subject to the requirements of this
subpart shall comply with the emission limitations set forth in this
section on and after the date on which the initial performance test,
required by Sec. 60.8, is completed, but not later than 60 days after
achieving the maximum production rate at which the affected facility
will be operated, or 180 days after initial startup, whichever comes
first.
(a) No owner or operator subject to the provisions of this subpart
shall:
(1) Burn in any fuel gas combustion device any fuel gas that
contains hydrogen sulfide (H2S) in excess of 230 mg/dscm
(0.10 gr/dscf). The combustion in a flare of process upset gases or fuel
gas that is released to the flare as a result of relief valve leakage or
other emergency malfunctions is exempt from this paragraph.
(2) Discharge or cause the discharge of any gases into the
atmosphere from any Claus sulfur recovery plant containing in excess of:
(i) For an oxidation control system or a reduction control system
followed by incineration, 250 ppm by volume (dry basis) of sulfur
dioxide (SO2) at zero percent excess air.
(ii) For a reduction control system not followed by incineration,
300 ppm by volume of reduced sulfur compounds and 10 ppm by volume of
hydrogen sulfide (H2S), each calculated as ppm SO2
by volume (dry basis) at zero percent excess air.
(b) Each owner or operator that is subject to the provisions of this
subpart shall comply with one of the following conditions for each
affected fluid catalytic cracking unit catalyst regenerator:
(1) With an add-on control device, reduce sulfur dioxide emissions
to the atmosphere by 90 percent or maintain sulfur dioxide emissions to
the atmosphere less than or equal to 50 ppm by volume (vppm), whichever
is less stringent; or
(2) Without the use of an add-on control device, maintain sulfur
oxides emissions calculated as sulfur dioxide to the atmosphere less
than or equal to 9.8 kg/Mg (20 lb/ton) coke burn-off; or
(3) Process in the fluid catalytic cracking unit fresh feed that has
a total sulfur content no greater than 0.30 percent by weight.
(c) Compliance with paragraph (b)(1), (b)(2), or (b)(3) of this
section is determined daily on a 7-day rolling average basis using the
appropriate procedures outlined in Sec. 60.106.
(d) A minimum of 22 valid days of data shall be obtained every 30
rolling
[[Page 214]]
successive calendar days when complying with paragraph (b)(1) of this
section.
[43 FR 10869, Mar. 15, 1978, as amended at 54 FR 34027, Aug. 17, 1989;
55 FR 40175, Oct. 2, 1990; 65 FR 61754, Oct. 17, 2000]
Sec. 60.105 Monitoring of emissions and operations.
(a) Continuous monitoring systems shall be installed, calibrated,
maintained, and operated by the owner or operator subject to the
provisions of this subpart as follows:
(1) For fluid catalytic cracking unit catalyst regenerators subject
to Sec. 60.102(a)(2), an instrument for continuously monitoring and
recording the opacity of emissions into the atmosphere. The instrument
shall be spanned at 60, 70, or 80 percent opacity.
(2) For fluid catalytic cracking unit catalyst regenerators subject
to Sec. 60.103(a), an instrument for continuously monitoring and
recording the concentration by volume (dry basis) of CO emissions into
the atmosphere, except as provided in paragraph (a)(2) (ii) of this
section.
(i) The span value for this instrument is 1,000 ppm CO.
(ii) A CO continuous monitoring system need not be installed if the
owner or operator demonstrates that the average CO emissions are less
than 50 ppm (dry basis) and also files a written request for exemption
to the Administrator and receives such an exemption. The demonstration
shall consist of continuously monitoring CO emissions for 30 days using
an instrument that shall meet the requirements of Performance
Specification 4 of Appendix B of this part. The span value shall be 100
ppm CO instead of 1,000 ppm, and the relative accuracy limit shall be 10
percent of the average CO emissions or 5 ppm CO, whichever is greater.
For instruments that are identical to Method 10 and employ the sample
conditioning system of Method 10A, the alternative relative accuracy
test procedure in Sec. 10.1 of Performance Specification 2 may be used
in place of the relative accuracy test.
(3) For fuel gas combustion devices subject to Sec. 60.104(a)(1), an
instrument for continuously monitoring and recording the concentration
by volume (dry basis, zero percent excess air) of SO2
emissions into the atmosphere (except where an H2S monitor is
installed under paragraph (a)(4) of this section). The monitor shall
include an oxygen monitor for correcting the data for excess air.
(i) The span values for this monitor are 50 ppm SO2 and
25 percent oxygen (O2).
(ii) The SO2 monitoring level equivalent to the
H2S standard under Sec. 60.104(a)(1) shall be 20 ppm (dry
basis, zero percent excess air).
(iii) The performance evaluations for this SO2 monitor
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations. Method 6 samples shall be taken at a flow rate of
approximately 2 liters/min for at least 30 minutes. The relative
accuracy limit shall be 20 percent or 4 ppm, whichever is greater, and
the calibration drift limit shall be 5 percent of the established span
value.
(iv) Fuel gas combustion devices having a common source of fuel gas
may be monitored at only one location (i.e., after one of the combustion
devices), if monitoring at this location accurately represents the
S2 emissions into the atmosphere from each of the combustion
devices.
(4) In place of the SO2 monitor in paragraph (a)(3) of
this section, an instrument for continuously monitoring and recording
the concentration (dry basis) of H2S in fuel gases before
being burned in any fuel gas combustion device.
(i) The span value for this instrument is 425 mg/dscm
H2S.
(ii) Fuel gas combustion devices having a common source of fuel gas
may be monitored at only one location, if monitoring at this location
accurately represents the concentration of H2S in the fuel
gas being burned.
(iii) The performance evaluations for this H2S monitor
under Sec. 60.13(c) shall use Performance Specification 7. Method 11,
15, 15A, or 16 shall be used for conducting the relative accuracy
evaluations.
(5) For Claus sulfur recovery plants with oxidation control systems
or reduction control systems followed by incineration subject to
Sec. 60.104(a)(2)(i), an
[[Page 215]]
instrument for continuously monitoring and recording the concentration
(dry basis, zero percent excess air) of SO2 emissions into
the atmosphere. The monitor shall include an oxygen monitor for
correcting the data for excess air.
(i) The span values for this monitor are 500 ppm SO2 and
25 percent O2.
(ii) The performance evaluations for this SO2 monitor
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations.
(6) For Claus sulfur recovery plants with reduction control systems
not followed by incineration subject to Sec. 60.104(a)(2)(ii), an
instrument for continuously monitoring and recording the concentration
of reduced sulfur and O2 emissions into the atmosphere. The
reduced sulfur emissions shall be calculated as SO2 (dry
basis, zero percent excess air).
(i) The span values for this monitor are 450 ppm reduced sulfur and
25 percent O2.
(ii) The performance evaluations for this reduced sulfur (and
O2) monitor under Sec. 60.13(c) shall use Performance
Specification 5 of Appendix B of this Part (and Performance
Specification 3 of Appendix B of this Part for the O2
analyzer). Methods 15 or 15A and Method 3 shall be used for conducting
the relative accuracy evaluations. If Method 3 yields O2
concentrations below 0.25 percent during the performance specification
test, the O2 concentration may be assumed to be zero and the
reduced sulfur CEMS need not include an O2 monitor.
(7) In place of the reduced sulfur monitor under paragraph (a)(6) of
this section, an instrument using an air or O2 dilution and
oxidation system to convert the reduced sulfur to SO2 for
continuously monitoring and recording the concentration (dry basis, zero
percent excess air) of the resultant SO2. The monitor shall
include an oxygen monitor for correcting the data for excess oxygen.
(i) The span values for this monitor are 375 ppm SO2 and
25 percent O2.
(ii) For reporting purposes, the SO2 exceedance level for
this monitor is 250 ppm (dry basis, zero percent excess air).
(iii) The performance evaluations for this SO2 (and
O2) monitor under Sec. 60.13(c) shall use Performance
Specification 5. Methods 15 or 15A and Method 3 shall be used for
conducting the relative accuracy evaluations.
(8) An instrument for continuously monitoring and recording
concentrations of SO2 in the gases at both the inlet and
outlet of the SO2 control device from any fluid catalytic
cracking unit catalyst regenerator for which the owner or operator seeks
to comply with Sec. 60.104 (b)(1).
(i) The span value of the inlet monitor shall be set 125 percent of
the maximum estimated hourly potential SO2 emission
concentration entering the control device, and the span value of the
outlet monitor shall be set at 50 percent of the maximum estimated
hourly potential sulfur dioxide emission concentration entering the
control device.
(ii) The performance evaluations for these SO2 monitors
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations.
(9) An instrument for continuously monitoring and recording
concentrations of SO2 in the gases discharged into the
atmosphere from any fluid catalytic cracking unit catalyst regenerator
for which the owner or operator seeks to comply specifically with the 50
ppmv emission limit under Sec. 60.104 (b)(1).
(i) The span value of the monitor shall be set at 50 percent of the
maximum hourly potential SO2 emission concentration of the
control device.
(ii) The performance evaluations for this SO2 monitor
under Sec. 60.13 (c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations.
(10) An instrument for continuously monitoring and recording
concentrations of oxygen (O2) in the gases at both the inlet
and outlet of the sulfur dioxide control device (or the outlet only if
specifically complying with the
[[Page 216]]
50 ppmv standard) from any fluid catalytic cracking unit catalyst
regenerator for which the owner or operator has elected to comply with
Sec. 60.104(b)(1). The span of this continuous monitoring system shall
be set at 10 percent.
(11) The continuous monitoring systems under paragraphs (a)(8),
(a)(9), and (a)(10) of this section are operated and data recorded
during all periods of operation of the affected facility including
periods of startup, shutdown, or malfunction, except for continuous
monitoring system breakdowns, repairs, calibration checks, and zero and
span adjustments.
(12) The owner or operator shall use the following procedures to
evaluate the continuous monitoring systems under paragraphs (a)(8),
(a)(9), and (a)(10) of this section.
(i) Method 3 or 3A and Method 6 or 6C for the relative accuracy
evaluations under the Sec. 60.13(e) performance evaluation.
(ii) Appendix F, Procedure 1, including quarterly accuracy
determinations and daily calibration drift tests.
(13) When seeking to comply with Sec. 60.104(b)(1), when emission
data are not obtained because of continuous monitoring system
breakdowns, repairs, calibration checks and zero and span adjustments,
emission data will be obtained by using one of the following methods to
provide emission data for a minimum of 18 hours per day in at least 22
out of 30 rolling successive calendar days.
(i) The test methods as described in Sec. 60.106(k);
(ii) A spare continuous monitoring system; or
(iii) Other monitoring systems as approved by the Administrator.
(b) [Reserved]
(c) The average coke burn-off rate (Mg (tons) per hour) and hours of
operation shall be recorded daily for any fluid catalytic cracking unit
catalyst regenerator subject to Sec. 60.102, Sec. 60.103, or
Sec. 60.104(b)(2).
(d) For any fluid catalytic cracking unit catalyst regenerator under
Sec. 60.102 that uses an incinerator-waste heat boiler to combust the
exhaust gases from the catalyst regenerator, the owner or operator shall
record daily the rate of combustion of liquid or solid fossil-fuels and
the hours of operation during which liquid or solid fossil-fuels are
combusted in the incinerator-waste heat boiler.
(e) For the purpose of reports under Sec. 60.7(c), periods of excess
emissions that shall be determined and reported are defined as follows:
Note: All averages, except for opacity, shall be determined as the
arithmetic average of the applicable 1-hour averages, e.g., the rolling
3-hour average shall be determined as the arithmetic average of three
contiguous 1-hour averages.
(1) Opacity. All 1-hour periods that contain two or more 6-minute
periods during which the average opacity as measured by the continuous
monitoring system under Sec. 60.105(a)(1) exceeds 30 percent.
(2) Carbon monoxide. All 1-hour periods during which the average CO
concentration as measured by the CO continuous monitoring system under
Sec. 60.105(a)(2) exceeds 500 ppm.
(3) Sulfur dioxide from fuel gas combustion. (i) All rolling 3-hour
periods during which the average concentration of SO2 as
measured by the SO2 continuous monitoring system under
Sec. 60.105(a)(3) exceeds 20 ppm (dry basis, zero percent excess air);
or
(ii) All rolling 3-hour periods during which the average
concentration of H2S as measured by the H2S
continuous monitoring system under Sec. 60.105(a)(4) exceeds 230 mg/dscm
(0.10 gr/dscf).
(4) Sulfur dioxide from Claus sulfur recovery plants. (i) All 12-
hour periods during which the average concentration of SO2 as
measured by the SO2 continuous monitoring system under
Sec. 60.105(a)(5) exceeds 250 ppm (dry basis, zero percent excess air);
or
(ii) All 12-hour periods during which the average concentration of
reduced sulfur (as SO2) as measured by the reduced sulfur
continuous monitoring system under Sec. 60.105(a)(6) exceeds 300 ppm; or
(iii) All 12-hour periods during which the average concentration of
SO2 as
[[Page 217]]
measured by the SO2 continuous monitoring system under
Sec. 60.105(a)(7) exceeds 250 ppm (dry basis, zero percent excess air).
[39 FR 9315, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975; 42
FR 32427, June 24, 1977; 42 FR 39389, Aug. 4, 1977; 43 FR 10869, Mar.
15, 1978; 48 FR 23611, May 25, 1983; 50 FR 31701, Aug. 5, 1985; 54 FR
34028, Aug. 17, 1989; 55 FR 40175, Oct. 2, 1990; 65 FR 61754, Oct. 17,
2000]
Sec. 60.106 Test methods and procedures.
(a) In conducting the performance tests required in Sec. 60.8, the
owner or operator shall use as reference methods and procedures the test
methods in appendix A of this part or other methods and procedures as
specified in this section, except as provided in Sec. 60.8(b).
(b) The owner or operator shall determine compliance with the
particulate matter (PM) standards in Sec. 60.102(a) as follows:
(1) The emission rate (E) of PM shall be computed for each run using
the following equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.000
Where:
E = Emission rate of PM, kg/Mg (lb/ton) of coke burn-off.
cs = Concentration of PM, g/dscm (gr/dscf).
Qsd = Volumetric flow rate of effluent gas, dscm/hr (dscf/
hr).
Rc = Coke burn-off rate, Mg/hr (ton/hr) coke.
K=Conversion factor, 1,000 g/kg (7,000 gr/lb).
(2) Method 5B or 5F is to be used to determine particulate matter
emissions and associated moisture content from affected facilities
without wet FGD systems; only Method 5B is to be used after wet FGD
systems. The sampling time for each run shall be at least 60 minutes and
the sampling rate shall be at least 0.015 dscm/min (0.53 dscf/min),
except that shorter sampling times may be approved by the Administrator
when process variables or other factors preclude sampling for at least
60 minutes.
(3) The coke burn-off rate (Rc) shall be computed for
each run using the following equation:
Rc=K1Qr(%CO2+%CO)-
(K2Qa-K3Qr)((%CO/
2)+(%CO2+%O2))
Where:
Rc = Coke burn-off rate, Mg/hr (ton/hr).
Qr = Volumetric flow rate of exhaust gas from catalyst
regenerator before entering the emission control system, dscm/
min (dscf/min).
Qa = Volumetric flow rate of air to FCCU regenerator, as
determined from the fluid catalytic cracking unit control room
instrumentation, dscm/min (dscf/min).
%CO2 = Carbon dioxide concentration, percent by volume (dry
basis).
%CO = Carbon monoxide concentration, percent by volume (dry basis).
%O2 = Oxygen concentration, percent by volume (dry basis).
K1 = Material balance and conversion factor, 2.982 x
10-4 (Mg-min)/(hr-dscm-%) [9.31 x 10-6
(ton-min)/(hr-dscf-%)].
K2 = Material balance and conversion factor, 2.088 x
10-3 (Mg-min)/(hr-dscm-%) [6.52 x 10-5
(ton-min)/(hr-dscf-%)].
K3 = Material balance and conversion factor, 9.94 x
10-5 (Mg-min)/(hr-dscm-%) [3.1 x 10-6
(ton-min)/(hr-dscf-%)].
(i) Method 2 shall be used to determine the volumetric flow rate
(Qr).
(ii) The emission correction factor, integrated sampling and
analysis procedure of Method 3B shall be used to determine
CO2, CO, and O2 concentrations.
(4) Method 9 and the procedures of Sec. 60.11 shall be used to
determine opacity.
(c) If auxiliary liquid or solid fossil-fuels are burned in an
incinerator-waste heat boiler, the owner or operator shall determine the
emission rate of PM permitted in Sec. 60.102(b) as follows:
(1) The allowable emission rate (Es) of PM shall be
computed for each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.002
Where:
Es = Emission rate of PM allowed, kg/Mg (lb/ton) of coke
burn-off in catalyst regenerator.
[[Page 218]]
F=Emission standard, 1.0 kg/Mg (2.0 lb/ton) of coke burn-off in catalyst
regenerator.
A = Allowable incremental rate of PM emissions, 7.5 x 10-4
kg/million J (0.10 lb/million Btu).
H = Heat input rate from solid or liquid fossil fuel, million J/hr
(million Btu/hr).
Rc = Coke burn-off rate, Mg coke/hr (ton coke/hr).
(2) Procedures subject to the approval of the Administrator shall be
used to determine the heat input rate.
(3) The procedure in paragraph (b)(3) of this section shall be used
to determine the coke burn-off rate (Rc).
(d) The owner or operator shall determine compliance with the CO
standard in Sec. 60.103(a) by using the integrated sampling technique of
Method 10 to determine the CO concentration (dry basis). The sampling
time for each run shall be 60 minutes.
(e)(1) The owner or operator shall determine compliance with the
H2S standard in Sec. 60.104(a)(1) as follows: Method 11, 15,
15A, or 16 shall be used to determine the H2S concentration.
The gases entering the sampling train should be at about atmospheric
pressure. If the pressure in the refinery fuel gas lines is relatively
high, a flow control valve may be used to reduce the pressure. If the
line pressure is high enough to operate the sampling train without a
vacuum pump, the pump may be eliminated from the sampling train. The
sample shall be drawn from a point near the centroid of the fuel gas
line.
(i) For Method 11, the sampling time and sample volume shall be at
least 10 minutes and 0.010 dscm (0.35 dscf). Two samples of equal
sampling times shall be taken at about 1-hour intervals. The arithmetic
average of these two samples shall constitute a run. For most fuel
gases, sampling times exceeding 20 minutes may result in depletion of
the collection solution, although fuel gases containing low
concentrations of H2S may necessitate sampling for longer
periods of time.
(ii) For Method 15 or 16, at least three injects over a 1-hour
period shall constitute a run.
(iii) For Method 15A, a 1-hour sample shall constitute a run.
(2) Where emissions are monitored by Sec. 60.105(a)(3), compliance
with Sec. 60.105(a)(1) shall be determined using Method 6 or 6C and
Method 3 or 3A. A 1-hour sample shall constitute a run. Method 6 samples
shall be taken at a rate of approximately 2 liters/min. The ppm
correction factor (Method 6) and the sampling location in paragraph
(f)(1) of this section apply. Method 4 shall be used to determine the
moisture content of the gases. The sampling point for Method 4 shall be
adjacent to the sampling point for Method 6 or 6C.
(f) The owner or operator shall determine compliance with the
SO2 and the H2S and reduced sulfur standards in
Sec. 60.104(a)(2) as follows:
(1) Method 6 shall be used to determine the SO2
concentration. The concentration in mg/dscm obtained by Method 6 or 6C
is multiplied by 0.3754 to obtain the concentration in ppm. The sampling
point in the duct shall be the centroid of the cross section if the
cross-sectional area is less than 5.00 m2 (53.8
ft2) or at a point no closer to the walls than 1.00 m (39.4
in.) if the cross-sectional area is 5.00 m2 or more and the
centroid is more than 1 m from the wall. The sampling time and sample
volume shall be at least 10 minutes and 0.010 dscm (0.35 dscf) for each
sample. Eight samples of equal sampling times shall be taken at about
30-minute intervals. The arithmetic average of these eight samples shall
constitute a run. For Method 6C, a run shall consist of the arithmetic
average of four 1-hour samples. Method 4 shall be used to determine the
moisture content of the gases. The sampling point for Method 4 shall be
adjacent to the sampling point for Method 6 or 6C. The sampling time for
each sample shall be equal to the time it takes for two Method 6
samples. The moisture content from this sample shall be used to correct
the corresponding Method 6 samples for moisture. For documenting the
oxidation efficiency of the control device for reduced sulfur compounds,
Method 15 shall be used following the procedures of paragraph (f)(2) of
this section.
(2) Method 15 shall be used to determine the reduced sulfur and
H2 S concentrations. Each run shall consist of 16 samples
taken over a minimum of 3 hours. The sampling point shall be the same as
that described for Method 6 in paragraph (f)(1) of this section. To
ensure minimum residence time for the
[[Page 219]]
sample inside the sample lines, the sampling rate shall be at least 3.0
lpm (0.10 cfm). The SO2 equivalent for each run shall be
calculated after being corrected for moisture and oxygen as the
arithmetic average of the SO2 equivalent for each sample
during the run. Method 4 shall be used to determine the moisture content
of the gases as the paragraph (f)(1) of this section. The sampling time
for each sample shall be equal to the time it takes for four Method 15
samples.
(3) The oxygen concentration used to correct the emission rate for
excess air shall be obtained by the integrated sampling and analysis
procedure of Method 3 or 3A. The samples shall be taken simultaneously
with the SO2, reduced sulfur and H2S, or moisture
samples. The SO2, reduced sulfur, and H2S samples
shall be corrected to zero percent excess air using the equation in
paragraph (h)(6) of this section.
(g) Each performance test conducted for the purpose of determining
compliance under Sec. 60.104(b) shall consist of all testing performed
over a 7-day period using Method 6 or 6C and Method 3 or 3A. To
determine compliance, the arithmetic mean of the results of all the
tests shall be compared with the applicable standard.
(h) For the purpose of determining compliance with
Sec. 60.104(b)(1), the following calculation procedures shall be used:
(1) Calculate each 1-hour average concentration (dry, zero percent
oxygen, ppmv) of sulfur dioxide at both the inlet and the outlet to the
add-on control device as specified in Sec. 60.13(h). These calculations
are made using the emission data collected under Sec. 60.105(a).
(2) Calculate a 7-day average (arithmetic mean) concentration of
sulfur dioxide for the inlet and for the outlet to the add-on control
device using all of the 1-hour average concentration values obtained
during seven successive 24-hour periods.
(3) Calculate the 7-day average percent reduction using the
following equation:
Rso2 = 100(Cso2(i)-Cso2(o))/
Cso2(i)
where:
Rso2 = 7-day average sulfur dioxide emission reduction,
percent
Cso2(i) = sulfur dioxide emission concentration determined in
Sec. 60.106(h)(2) at the inlet to the add-on control device, ppmv
Cso2(o) = sulfur dioxide emission concentration determined in
Sec. 60.106(h)(2) at the outlet to the add-on control device, ppmv
100 = conversion factor, decimal to percent
(4) Outlet concentrations of sulfur dioxide from the add-on control
device for compliance with the 50 ppmv standard, reported on a dry,
O2-free basis, shall be calculated using the procedures
outlined in Sec. 60.106(h)(1) and (2) above, but for the outlet monitor
only.
(5) If supplemental sampling data are used for determining the 7-day
averages under paragraph (h) of this section and such data are not
hourly averages, then the value obtained for each supplemental sample
shall be assumed to represent the hourly average for each hour over
which the sample was obtained.
(6) For the purpose of adjusting pollutant concentrations to zero
percent oxygen, the following equation shall be used:
Cadj = Cmeas [20.9c/
(20.9-%O2)]
where:
Cadj = pollutant concentration adjusted to zero percent
oxygen, ppm or g/dscm
Cmeas = pollutant concentration measured on a dry basis, ppm
or g/dscm
20.9c = 20.9 percent oxygen-0.0 percent oxygen (defined
oxygen correction basis), percent
20.9 = oxygen concentration in air, percent
%O2 = oxygen concentration measured on a dry basis, percent
(i) For the purpose of determining compliance with
Sec. 60.104(b)(2), the following reference methods and calculation
procedures shall be used except as provided in paragraph (i)(12) of this
section:
(1) One 3-hour test shall be performed each day.
(2) For gases released to the atmosphere from the fluid catalytic
cracking unit catalyst regenerator:
(i) Method 8 as modified in Sec. 60.106(i)(3) for moisture content
and for the concentration of sulfur oxides calculated as sulfur dioxide,
(ii) Method 1 for sample and velocity traverses,
(iii) Method 2 calculation procedures (data obtained from Methods 3
and 8)
[[Page 220]]
for velocity and volumetric flow rate, and
(iv) Method 3 for gas analysis.
(3) Method 8 shall be modified by the insertion of a heated glass
fiber filter between the probe and first impinger. The probe liner and
glass fiber filter temperature shall be maintained above 160 deg.C (320
deg.F). The isopropanol impinger shall be eliminated. Sample recovery
procedures described in Method 8 for container No. 1 shall be
eliminated. The heated glass fiber filter also shall be excluded;
however, rinsing of all connecting glassware after the heated glass
fiber filter shall be retained and included in container No. 2. Sampled
volume shall be at least 1 dscm.
(4) For Method 3, the integrated sampling technique shall be used.
(5) Sampling time for each run shall be at least 3 hours.
(6) All testing shall be performed at the same location. Where the
gases discharged by the fluid catalytic cracking unit catalyst
regenerator pass through an incinerator-waste heat boiler in which
auxiliary or supplemental gaseous, liquid, or solid fossil fuel is
burned, testing shall be conducted at a point between the regenerator
outlet and the incinerator-waste heat boiler. An alternative sampling
location after the waste heat boiler may be used if alternative coke
burn-off rate equations, and, if requested, auxiliary/supplemental fuel
SOX credits, have been submitted to and approved by the
Administrator prior to sampling.
(7) Coke burn-off rate shall be determined using the procedures
specified under paragraph (b)(3) of this section, unless paragraph
(i)(6) of this section applies.
(8) Calculate the concentration of sulfur oxides as sulfur dioxide
using equation 8-3 in Section 6.5 of Method 8 to calculate and report
the total concentration of sulfur oxides as sulfur dioxide
(Cso x).
(9) Sulfur oxides emission rate calculated as sulfur dioxide shall
be determined for each test run by the following equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.003
Where:
ESOx = sulfur oxides emission rate calculated as sulfur
dioxide, kg/hr (lb/hr)
CSOx = sulfur oxides emission concentration calculated as
sulfur dioxide, g/dscm (gr/dscf)
Qsd = dry volumetric stack gas flow rate corrected to
standard conditions, dscm/hr (dscf/hr)
K=1,000 g/kg (7,000 gr/lb)
(10) Sulfur oxides emissions calculated as sulfur dioxide shall be
determined for each test run by the following equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.004
Where:
RSOx = Sulfur oxides emissions calculated as kg sulfur
dioxide per Mg (lb/ton) coke burn-off.
ESOx = Sulfur oxides emission rate calculated as sulfur
dioxide, kg/hr (lb/hr).
Rc = Coke burn-off rate, Mg/hr (ton/hr).
(11) Calculate the 7-day average sulfur oxides emission rate as
sulfur dioxide per Mg (ton) of coke burn-off by dividing the sum of the
individual daily rates by the number of daily rates summed.
(12) An owner or operator may, upon approval by the Administrator,
use an alternative method for determining compliance with
Sec. 60.104(b)(2), as provided in Sec. 60.8(b). Any requests for
approval must include data to demonstrate to the Administrator that the
alternative method would produce results adequate for the determination
of compliance.
(j) For the purpose of determining compliance with
Sec. 60.104(b)(3), the following analytical methods and calculation
procedures shall be used:
(1) One fresh feed sample shall be collected once per 8-hour period.
(2) Fresh feed samples shall be analyzed separately by using any one
of the following applicable analytical test methods: ASTM D129-64, 78,
or 95, ASTM D1552-83 or 95, ASTM D2622-87, 94, or 98, or ASTM D1266-87,
91, or 98. (These methods are incorporated by reference: see
Sec. 60.17.) The applicable range of some of these ASTM methods is not
adequate to measure the levels of sulfur in some fresh feed samples.
Dilution of samples prior to analysis with verification of the dilution
ratio
[[Page 221]]
is acceptable upon prior approval of the Administrator.
(3) If a fresh feed sample cannot be collected at a single location,
then the fresh feed sulfur content shall be determined as follows:
(i) Individual samples shall be collected once per 8-hour period for
each separate fresh feed stream charged directly into the riser or
reactor of the fluid catalytic cracking unit. For each sample location
the fresh feed volumetric flow rate at the time of collecting the fresh
feed sample shall be measured and recorded. The same method for
measuring volumetric flow rate shall be used at all locations.
(ii) Each fresh feed sample shall be analyzed separately using the
methods specified under paragraph (j)(2) of this section.
(iii) Fresh feed sulfur content shall be calculated for each 8-hour
period using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.005
where:
Sf = fresh feed sulfur content expressed in percent by weight
of fresh feed.
n = number of separate fresh feed streams charged directly to the riser
or reactor of the fluid catalytic cracking unit.
Qf = total volumetric flow rate of fresh feed charged to the
fluid catalytic cracking unit.
Si = fresh feed sulfur content expressed in percent by weight
of fresh feed for the ``ith'' sampling location.
Qi = volumetric flow rate of fresh feed stream for the
``ith'' sampling location.
(4) Calculate a 7-day average (arithmetic mean) sulfur content of
the fresh feed using all of the fresh feed sulfur content values
obtained during seven successive 24-hour periods.
(k) The test methods used to supplement continuous monitoring system
data to meet the minimum data requirements in Sec. 60.104(d) will be
used as described below or as otherwise approved by the Administrator.
(1) Methods 6, 6B, or 8 are used. The sampling location(s) are the
same as those specified for the monitor.
(2) For Method 6, the minimum sampling time is 20 minutes and the
minimum sampling volume is 0.02 dscm (0.71 dscf) for each sample.
Samples are taken at approximately 60-minute intervals. Each sample
represents a 1-hour average. A minimum of 18 valid samples is required
to obtain one valid day of data.
(3) For Method 6B, collection of a sample representing a minimum of
18 hours is required to obtain one valid day of data.
(4) For Method 8, the procedures as outlined in this section are
used. The equivalent of 16 hours of sampling is required to obtain one
valid day of data.
[39 FR 9315, Mar. 8, 1974, as amended at 43 FR 10869, Mar. 15, 1978; 51
FR 42842, Nov. 26, 1986; 52 FR 20392, June 1, 1987; 53 FR 41333, Oct.
21, 1988; 54 FR 34028, Aug. 17, 1989; 55 FR 40176, Oct. 2, 1990; 56 FR
4176, Feb. 4, 1991; 65 FR 61754, Oct. 17, 2000]
Sec. 60.107 Reporting and recordkeeping requirements.
(a) Each owner or operator subject to Sec. 60.104(b) shall notify
the Administrator of the specific provisions of Sec. 60.104(b) with
which the owner or operator seeks to comply. Notification shall be
submitted with the notification of initial startup required by
Sec. 60.7(a)(3). If an owner or operator elects at a later date to
comply with an alternative provision of Sec. 60.104(b), then the
Administrator shall be notified by the owner or operator in the report
described in paragraph (c) of this section.
(b) Each owner or operator subject to Sec. 60.104(b) shall record
and maintain the following information:
(1) If subject to Sec. 60.104(b)(1),
(i) All data and calibrations from continuous monitoring systems
located at the inlet and outlet to the control device, including the
results of the daily drift tests and quarterly accuracy assessments
required under appendix F, Procedure 1;
(ii) Measurements obtained by supplemental sampling (refer to
Sec. 60.105(a)(13) and Sec. 60.106(k)) for meeting minimum data
requirements; and
(iii) The written procedures for the quality control program
required by appendix F, Procedure 1.
(2) If subject to Sec. 60.104(b)(2), measurements obtained in the
daily Method 8 testing, or those obtained by alternative measurement
methods, if Sec. 60.106(i)(12) applies.
[[Page 222]]
(3) If subject to Sec. 60.104(b)(3), data obtained from the daily
feed sulfur tests.
(4) Each 7-day rolling average compliance determination.
(c) Each owner or operator subject to Sec. 60.104(b) shall submit a
report except as provided by paragraph (d) of this section. The
following information shall be contained in the report:
(1) Any 7-day period during which:
(i) The average percent reduction and average concentration of
sulfur dioxide on a dry, O2-free basis in the gases
discharged to the atmosphere from any fluid cracking unit catalyst
regenerator for which the owner or operator seeks to comply with
Sec. 60.104(b)(1) is below 90 percent and above 50 vppm, as measured by
the continuous monitoring system prescribed under Sec. 60.105(a)(8), or
above 50 vppm, as measured by the outlet continuous monitoring system
prescribed under Sec. 60.105(a)(9). The average percent reduction and
average sulfur dioxide concentration shall be determined using the
procedures specified under Sec. 60.106(h);
(ii) The average emission rate of sulfur dioxide in the gases
discharged to the atmosphere from any fluid catalytic cracking unit
catalyst regenerator for which the owner or operator seeks to comply
with Sec. 60.104(b)(2) exceeds 9.8 kg SOX per 1,000 kg coke
burn-off, as measured by the daily testing prescribed under
Sec. 60.106(i). The average emission rate shall be determined using the
procedures specified under Sec. 60.106(i); and
(iii) The average sulfur content of the fresh feed for which the
owner or operator seeks to comply with Sec. 60.104(b)(3) exceeds 0.30
percent by weight. The fresh feed sulfur content, a 7-day rolling
average, shall be determined using the procedures specified under
Sec. 60.106(j).
(2) Any 30-day period in which the minimum data requirements
specified in Sec. 60.104(d) are not obtained.
(3) For each 7-day period during which an exceedance has occurred as
defined in paragraphs (c)(1)(i) through (c)(1)(iii) and (c)(2) of this
section:
(i) The date that the exceedance occurred;
(ii) An explanation of the exceedance;
(iii) Whether the exceedance was concurrent with a startup,
shutdown, or malfunction of the fluid catalytic cracking unit or control
system; and
(iv) A description of the corrective action taken, if any.
(4) If subject to Sec. 60.104(b)(1),
(i) The dates for which and brief explanations as to why fewer than
18 valid hours of data were obtained for the inlet continuous monitoring
system;
(ii) The dates for which and brief explanations as to why fewer than
18 valid hours of data were obtained for the outlet continuous
monitoring system;
(iii) Identification of times when hourly averages have been
obtained based on manual sampling methods;
(iv) Identification of the times when the pollutant concentration
exceeded full span of the continuous monitoring system; and
(v) Description of any modifications to the continuous monitoring
system that could affect the ability of the continuous monitoring system
to comply with Performance Specifications 2 or 3.
(vi) Results of daily drift tests and quarterly accuracy assessments
as required under appendix F, Procedure 1.
(5) If subject to Sec. 60.104(b)(2), for each day in which a Method
8 sample result required by Sec. 60.106(i) was not obtained, the date
for which and brief explanation as to why a Method 8 sample result was
not obtained, for approval by the Administrator.
(6) If subject to Sec. 60.104(b)(3), for each 8-hour period in which
a feed sulfur measurement required by Sec. 60.106(j) was not obtained,
the date for which and brief explanation as to why a feed sulfur
measurement was not obtained, for approval by the Administrator.
(d) For any periods for which sulfur dioxide or oxides emissions
data are not available, the owner or operator of the affected facility
shall submit a signed statement indicating if any changes were made in
operation of the emission control system during the period of data
unavailability which could affect the ability of the system to meet the
applicable emission limit. Operations of the control system and affected
facility during periods of data unavailability are to be compared with
[[Page 223]]
operation of the control system and affected facility before and
following the period of data unavailability.
(e) The owner or operator of an affected facility shall submit the
reports required under this subpart to the Administrator semiannually
for each six-month period. All semiannual reports shall be postmarked by
the 30th day following the end of each six-month period.
(f) The owner or operator of the affected facility shall submit a
signed statement certifying the accuracy and completeness of the
information contained in the report.
[54 FR 34029, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990; 64
FR 7465, Feb. 12, 1999; 65 FR 61755, Oct. 17, 2000]
Sec. 60.108 Performance test and compliance provisions.
(a) Section 60.8(d) shall apply to the initial performance test
specified under paragraph (c) of this section, but not to the daily
performance tests required thereafter as specified in Sec. 60.108(d).
Section 60.8(f) does not apply when determining compliance with the
standards specified under Sec. 60.104(b). Performance tests conducted
for the purpose of determining compliance under Sec. 60.104(b) shall be
conducted according to the applicable procedures specified under
Sec. 60.106.
(b) Owners or operators who seek to comply with Sec. 60.104(b)(3)
shall meet that standard at all times, including periods of startup,
shutdown, and malfunctions.
(c) The initial performance test shall consist of the initial 7-day
average calculated for compliance with Sec. 60.104(b)(1), (b)(2), or
(b)(3).
(d) After conducting the initial performance test prescribed under
Sec. 60.8, the owner or operator of a fluid catalytic cracking unit
catalyst regenerator subject to Sec. 60.104(b) shall conduct a
performance test for each successive 24-hour period thereafter. The
daily performance tests shall be conducted according to the appropriate
procedures specified under Sec. 60.106. In the event that a sample
collected under Sec. 60.106(i) or (j) is accidentally lost or conditions
occur in which one of the samples must be discontinued because of forced
shutdown, failure of an irreplaceable portion of the sample train,
extreme meteorological conditions, or other circumstances, beyond the
owner or operators' control, compliance may be determined using
available data for the 7-day period.
(e) Each owner or operator subject to Sec. 60.104(b) who has
demonstrated compliance with one of the provisions of Sec. 60.104(b) but
a later date seeks to comply with another of the provisions of
Sec. 60.104(b) shall begin conducting daily performance tests as
specified under paragraph (d) of this section immediately upon electing
to become subject to one of the other provisions of Sec. 60.104(b). The
owner or operator shall furnish the Administrator with a written
notification of the change in the semiannual report required by
Sec. 60.107(e).
[54 FR 34030, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990; 64
FR 7466, Feb. 12, 1999]
Sec. 60.109 Delegation of authority.
(a) In delegating implementation and enforcement authority to a
State under section 111(c) of the Act, the authorities contained in
paragraph (b) of this section shall be retained by the Administrator and
not transferred to a State.
(b) Authorities which shall not be delegated to States:
(1) Section 60.105(a)(13)(iii),
(2) Section 60.106(i)(12).
[54 FR 34031, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990]
Subpart K--Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification
Commenced After June 11, 1973, and Prior to May 19, 1978
Sec. 60.110 Applicability and designation of affected facility.
(a) Except as provided in Sec. 60.110(b), the affected facility to
which this subpart applies is each storage vessel for petroleum liquids
which has a storage capacity greater than 151,412 liters (40,000
gallons).
[[Page 224]]
(b) This subpart does not apply to storage vessels for petroleum or
condensate stored, processed, and/or treated at a drilling and
production facility prior to custody transfer.
(c) Subject to the requirements of this subpart is any facility
under paragraph (a) of this section which:
(1) Has a capacity greater than 151, 416 liters (40,000 gallons),
but not exceeding 246,052 liters (65,000 gallons), and commences
construction or modification after March 8, 1974, and prior to May 19,
1978.
(2) Has a capacity greater than 246,052 liters (65,000 gallons) and
commences construction or modification after June 11, 1973, and prior to
May 19, 1978.
[42 FR 37937, July 25, 1977, as amended at 45 FR 23379, Apr. 4, 1980]
Sec. 60.111 Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Act and in subpart A of this part.
(a) Storage vessel means any tank, reservoir, or container used for
the storage of petroleum liquids, but does not include:
(1) Pressure vessels which are designed to operate in excess of 15
pounds per square inch gauge without emissions to the atmosphere except
under emergency conditions,
(2) Subsurface caverns or porous rock reservoirs, or
(3) Underground tanks if the total volume of petroleum liquids added
to and taken from a tank annually does not exceed twice the volume of
the tank.
(b) Petroleum liquids means petroleum, condensate, and any finished
or intermediate products manufactured in a petroleum refinery but does
not mean Nos. 2 through 6 fuel oils as specified in ASTM D396-78, 89,
90, 92, 96, or 98, gas turbine fuel oils Nos. 2-GT through 4-GT as
specified in ASTM D2880-78 or 96, or diesel fuel oils Nos. 2-D and 4-D
as specified in ASTM D975-78, 96, or 98a. (These three methods are
incorporated by reference--see Sec. 60.17.)
(c) Petroleum refinery means each facility engaged in producing
gasoline, kerosene, distillate fuel oils, residual fuel oils,
lubricants, or other products through distillation of petroleum or
through redistillation, cracking, extracting, or reforming of unfinished
petroleum derivatives.
(d) Petroleum means the crude oil removed from the earth and the
oils derived from tar sands, shale, and coal.
(e) Hydrocarbon means any organic compound consisting predominantly
of carbon and hydrogen.
(f) Condensate means hydrocarbon liquid separated from natural gas
which condenses due to changes in the temperature and/or pressure and
remains liquid at standard conditions.
(g) Custody transfer means the transfer of produced petroleum and/or
condensate, after processing and/or treating in the producing
operations, from storage tanks or automatic transfer facilities to
pipelines or any other forms of transportation.
(h) Drilling and production facility means all drilling and
servicing equipment, wells, flow lines, separators, equipment, gathering
lines, and auxiliary nontransportation-related equipment used in the
production of petroleum but does not include natural gasoline plants.
(i) True vapor pressure means the equilibrium partial pressure
exerted by a petroleum liquid as determined in accordance with methods
described in American Petroleum Institute Bulletin 2517, Evaporation
Loss from External Floating-Roof Tanks, Second Edition, February 1980
(incorporated by reference--see Sec. 60.17).
(j) Floating roof means a storage vessel cover consisting of a
double deck, pontoon single deck, internal floating cover or covered
floating roof, which rests upon and is supported by the petroleum liquid
being contained, and is equipped with a closure seal or seals to close
the space between the roof edge and tank wall.
(k) Vapor recovery system means a vapor gathering system capable of
collecting all hydrocarbon vapors and gases discharged from the storage
vessel and a vapor disposal system capable of processing such
hydrocarbon vapors and gases so as to prevent their emission to the
atmosphere.
(l) Reid vapor pressure is the absolute vapor pressure of volatile
crude oil and volatile nonviscous petroleum liquids,
[[Page 225]]
except liquified petroleum gases, as determined by ASTM D323-82 or 94
(incorporated by reference--see Sec. 60.17).
[39 FR 9317, Mar. 8, 1974; 39 FR 13776, Apr. 17, 1974, as amended at 39
FR 20794, June 14, 1974; 45 FR 23379, Apr. 4, 1980; 48 FR 3737, Jan. 27,
1983; 52 FR 11429, Apr. 8, 1987; 65 FR 61755, Oct. 17, 2000]
Sec. 60.112 Standard for volatile organic compounds (VOC).
(a) The owner or operator of any storage vessel to which this
subpart applies shall store petroleum liquids as follows:
(1) If the true vapor pressure of the petroleum liquid, as stored,
is equal to or greater than 78 mm Hg (1.5 psia) but not greater than 570
mm Hg (11.1 psia), the storage vessel shall be equipped with a floating
roof, a vapor recovery system, or their equivalents.
(2) If the true vapor pressure of the petroleum liquid as stored is
greater than 570 mm Hg (11.1 psia), the storage vessel shall be equipped
with a vapor recovery system or its equivalent.
[39 FR 9317, Mar. 8, 1974; 39 FR 13776, Apr. 17, 1974, as amended at 45
FR 23379, Apr. 4, 1980]
Sec. 60.113 Monitoring of operations.
(a) Except as provided in paragraph (d) of this section, the owner
or operator subject to this subpart shall maintain a record of the
petroleum liquid stored, the period of storage, and the maximum true
vapor pressure of that liquid during the respective storage period.
(b) Available data on the typical Reid vapor pressure and the
maximum expected storage temperature of the stored product may be used
to determine the maximum true vapor pressure from nomographs contained
in API Bulletin 2517, unless the Administrator specifically requests
that the liquid be sampled, the actual storage temperature determined,
and the Reid vapor pressure determined from the sample(s).
(c) The true vapor pressure of each type of crude oil with a Reid
vapor pressure less than 13.8 kPa (2.0 psia) or whose physical
properties preclude determination by the recommended method is to be
determined from available data and recorded if the estimated true vapor
pressure is greater than 6.9 kPa (1.0 psia).
(d) The following are exempt from the requirements of this section:
(1) Each owner or operator of each affected facility which stores
petroleum liquids with a Reid vapor pressure of less than 6.9 kPa (1.0
psia) provided the maximum true vapor pressure does not exceed 6.9 kPa
(1.0 psia).
(2) Each owner or operator of each affected facility equipped with a
vapor recovery and return or disposal system in accordance with the
requirements of Sec. 60.112.
[45 FR 23379, Apr. 4, 1980]
Subpart Ka--Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification
Commenced After May 18, 1978, and Prior to July 23, 1984
Sec. 60.110a Applicability and designation of affected facility.
(a) Affected facility. Except as provided in paragraph (b) of this
section, the affected facility to which this subpart applies is each
storage vessel with a storage capacity greater than 151,416 liters
(40,000 gallons) that is used to store petroleum liquids for which
construction is commenced after May 18, 1978.
(b) Each petroleum liquid storage vessel with a capacity of less
than 1,589,873 liters (420,000 gallons) used for petroleum or condensate
stored, processed, or treated prior to custody transfer is not an
affected facility and, therefore, is exempt from the requirements of
this subpart.
(c) Alternative means of compliance--(1) Option to comply with part
65. Owners or operators may choose to comply with 40 CFR part 65,
subpart C, to satisfy the requirements of Secs. 60.112a through 60.114a
for storage vessels that are subject to this subpart that store
petroleum liquids that, as stored, have a maximum true vapor pressure
equal to or greater than 10.3 kPa (1.5 psia). Other provisions applying
to owners or operators who choose to comply with
[[Page 226]]
40 CFR part 65 are provided in 40 CFR 65.1.
(2) Part 60, subpart A. Owners or operators who choose to comply
with 40 CFR part 65, subpart C, must also comply with Secs. 60.1, 60.2,
60.5, 60.6, 60.7(a)(1) and (4), 60.14, 60.15, and 60.16 for those
storage vessels. All sections and paragraphs of subpart A of this part
that are not mentioned in this paragraph (c)(2) do not apply to owners
or operators of storage vessels complying with 40 CFR part 65, subpart
C, except that provisions required to be met prior to implementing 40
CFR part 65 still apply. Owners and operators who choose to comply with
40 CFR part 65, subpart C, must comply with 40 CFR part 65, subpart A.
[45 FR 23379, Apr. 4, 1980, as amended at 65 FR 78275, Dec. 14, 2000]
Sec. 60.111a Definitions.
In addition to the terms and their definitions listed in the Act and
subpart A of this part the following definitions apply in this subpart:
(a) Storage vessel means each tank, reservoir, or container used for
the storage of petroleum liquids, but does not include:
(1) Pressure vessels which are designed to operate in excess of
204.9 kPa (15 psig) without emissions to the atmosphere except under
emergency conditions.
(2) Subsurface caverns or porous rock reservoirs, or
(3) Underground tanks if the total volume of petroleum liquids added
to and taken from a tank annually does not exceed twice the volume of
the tank.
(b) Petroleum liquids means petroleum, condensate, and any finished
or intermediate products manufactured in a petroleum refinery but does
not mean Nos. 2 through 6 fuel oils as specified in ASTM D396-78, 89,
90, 92, 96, or 98, gas turbine fuel oils Nos. 2-GT through 4-GT as
specified in ASTM D2880-78 or 96, gas turbine fuel oils Nos. 2-GT
through 4-GT as specified in ASTM D2880-78 or 96, or diesel fuel oils
Nos. 2-D and 4-D as specified in ASTM D975-78, 96, or 98a. (These three
methods are incorporated by reference--see Sec. 60.17.)
(c) Petroleum refinery means each facility engaged in producing
gasoline, kerosene, distillate fuel oils, residual fuel oils,
lubricants, or other products through distillation of petroleum or
through redistillation, cracking, extracting, or reforming of unfinished
petroleum derivatives.
(d) Petroleum means the crude oil removed from the earth and the
oils derived from tar sands, shale, and coal.
(e) Condensate means hydrocarbon liquid separated from natural gas
which condenses due to changes in the temperature or pressure, or both,
and remains liquid at standard conditions.
(f) True vapor pressure means the equilibrium partial pressure
exerted by a petroleum liquid such as determined in accordance with
methods described in American Petroleum Institute Bulletin 2517,
Evaporation Loss from External Floating-Roof Tanks, Second Edition,
February 1980 (incorporated by reference--see Sec. 60.17).
(g) Reid vapor pressure is the absolute vapor pressure of volatile
crude oil and nonviscous petroleum liquids, except liquified petroleum
gases, as determined by ASTM D323-82 or 94 (incorporated by reference--
see Sec. 60.17).
(h) Liquid-mounted seal means a foam or liquid-filled primary seal
mounted in contact with the liquid between the tank wall and the
floating roof continuously around the circumference of the tank.
(i) Metallic shoe seal includes but is not limited to a metal sheet
held vertically against the tank wall by springs or weighted levers and
is connected by braces to the floating roof. A flexible coated fabric
(envelope) spans the annular space between the metal sheet and the
floating roof.
(j) Vapor-mounted seal means a foam-filled primary seal mounted
continuously around the circumference of the tank so there is an annular
vapor space underneath the seal. The annular vapor space is bounded by
the bottom of the primary seal, the tank wall, the liquid surface, and
the floating roof.
(k) Custody transfer means the transfer of produced petroleum and/or
condensate, after processing and/or treating in the producing
operations, from
[[Page 227]]
storage tanks or automatic transfer facilities to pipelines or any other
forms of transportation.
[45 FR 23379, Apr. 4, 1980, as amended at 48 FR 3737, Jan. 27, 1983; 52
FR 11429, Apr. 8, 1987; 65 FR 61756, Oct. 17, 2000]
Sec. 60.112a Standard for volatile organic compounds (VOC).
(a) The owner or operator of each storage vessel to which this
subpart applies which contains a petroleum liquid which, as stored, has
a true vapor pressure equal to or greater than 10.3 kPa (1.5 psia) but
not greater than 76.6 kPa (11.1 psia) shall equip the storage vessel
with one of the following:
(1) An external floating roof, consisting of a pontoon-type or
double-deck-type cover that rests on the surface of the liquid contents
and is equipped with a closure device between the tank wall and the roof
edge. Except as provided in paragraph (a)(1)(ii)(D) of this section, the
closure device is to consist of two seals, one above the other. The
lower seal is referred to as the primary seal and the upper seal is
referred to as the secondary seal. The roof is to be floating on the
liquid at all times (i.e., off the roof leg supports) except during
initial fill and when the tank is completely emptied and subsequently
refilled. The process of emptying and refilling when the roof is resting
on the leg supports shall be continuous and shall be accomplished as
rapidly as possible.
(i) The primary seal is to be either a metallic shoe seal, a liquid-
mounted seal, or a vapor-mounted seal. Each seal is to meet the
following requirements:
(A) The accumulated area of gaps between the tank wall and the
metallic shoe seal or the liquid-mounted seal shall not exceed 212 cm\2\
per meter of tank diameter (10.0 in \2\per ft of tank diameter) and the
width of any portion of any gap shall not exceed 3.81 cm (1\1/2\ in).
(B) The accumulated area of gaps between the tank wall and the
vapor-mounted seal shall not exceed 21.2 cm\2\ per meter of tank
diameter (1.0 in\2\ per ft of tank diameter) and the width of any
portion of any gap shall not exceed 1.27 cm (\1/2\ in).
(C) One end of the metallic shoe is to extend into the stored liquid
and the other end is to extend a minimum vertical distance of 61 cm (24
in) above the stored liquid surface.
(D) There are to be no holes, tears, or other openings in the shoe,
seal fabric, or seal envelope.
(ii) The secondary seal is to meet the following requirements:
(A) The secondary seal is to be installed above the primary seal so
that it completely covers the space between the roof edge and the tank
wall except as provided in paragraph (a)(1)(ii)(B) of this section.
(B) The accumulated area of gaps between the tank wall and the
secondary seal used in combination with a metallic shoe or liquid-
mounted primary seal shall not exceed 21.2 cm\2\per meter of tank
diameter (1.0 in\2\per ft. of tank diameter) and the width of any
portion of any gap shall not exceed 1.27 cm (\1/2\ in.). There shall be
no gaps between the tank wall and the secondary seal used in combination
with a vapor-mounted primary seal.
(C) There are to be no holes, tears or other openings in the seal or
seal fabric.
(D) The owner or operator is exempted from the requirements for
secondary seals and the secondary seal gap criteria when performing gap
measurements or inspections of the primary seal.
(iii) Each opening in the roof except for automatic bleeder vents
and rim space vents is to provide a projection below the liquid surface.
Each opening in the roof except for automatic bleeder vents, rim space
vents and leg sleeves is to be equipped with a cover, seal or lid which
is to be maintained in a closed position at all times (i.e., no visible
gap) except when the device is in actual use or as described in pargraph
(a)(1)(iv) of this section. Automatic bleeder vents are to be closed at
all times when the roof is floating, except when the roof is being
floated off or is being landed on the roof leg supports. Rim vents are
to be set to open when the roof is being floated off the roof legs
supports or at the manufacturer's recommended setting.
[[Page 228]]
(iv) Each emergency roof drain is to be provided with a slotted
membrane fabric cover that covers at least 90 percent of the area of the
opening.
(2) A fixed roof with an internal floating type cover equipped with
a continuous closure device between the tank wall and the cover edge.
The cover is to be floating at all times, (i.e., off the leg supports)
except during initial fill and when the tank is completely emptied and
subsequently refilled. The process of emptying and refilling when the
cover is resting on the leg supports shall be continuous and shall be
accomplished as rapidly as possible. Each opening in the cover except
for automatic bleeder vents and the rim space vents is to provide a
projection below the liquid surface. Each opening in the cover except
for automatic bleeder vents, rim space vents, stub drains and leg
sleeves is to be equipped with a cover, seal, or lid which is to be
maintained in a closed position at all times (i.e., no visible gap)
except when the device is in actual use. Automatic bleeder vents are to
be closed at all times when the cover is floating except when the cover
is being floated off or is being landed on the leg supports. Rim vents
are to be set to open only when the cover is being floated off the leg
supports or at the manufacturer's recommended setting.
(3) A vapor recovery system which collects all VOC vapors and gases
discharged from the storage vessel, and a vapor return or disposal
system which is designed to process such VOC vapors and gases so as to
reduce their emission to the atmosphere by at least 95 percent by
weight.
(4) A system equivalent to those described in paragraphs (a)(1),
(a)(2), or (a)(3) of this section as provided in Sec. 60.114a.
(b) The owner or operator of each storage vessel to which this
subpart applies which contains a petroleum liquid which, as stored, has
a true vapor pressure greater than 76.6 kPa (11.1 psia), shall equip the
storage vessel with a vapor recovery system which collects all VOC
vapors and gases discharged from the storage vessel, and a vapor return
or disposal system which is designed to process such VOC vapors and
gases so as to reduce their emission to the atmosphere by at least 95
percent by weight.
[45 FR 23379, Apr. 4, 1980, as amended at 45 FR 83229, Dec. 18, 1980]
Sec. 60.113a Testing and procedures.
(a) Except as provided in Sec. 60.8(b) compliance with the standard
prescribed in Sec. 60.112a shall be determined as follows or in
accordance with an equivalent procedure as provided in Sec. 60.114a.
(1) The owner or operator of each storage vessel to which this
subpart applies which has an external floating roof shall meet the
following requirements:
(i) Determine the gap areas and maximum gap widths between the
primary seal and the tank wall and between the secondary seal and the
tank wall according to the following frequency:
(A) For primary seals, gap measurements shall be performed within 60
days of the initial fill with petroleum liquid and at least once every
five years thereafter. All primary seal inspections or gap measurements
which require the removal or dislodging of the secondary seal shall be
accomplished as rapidly as possible and the secondary seal shall be
replaced as soon as possible.
(B) For secondary seals, gap measurements shall be performed within
60 days of the initial fill with petroleum liquid and at least once
every year thereafter.
(C) If any storage vessel is out of service for a period of one year
or more, subsequent refilling with petroleum liquid shall be considered
initial fill for the purposes of paragraphs (a)(1)(i)(A) and
(a)(1)(i)(B) of this section.
(D) Keep records of each gap measurement at the plant for a period
of at least 2 years following the date of measurement. Each record shall
identify the vessel on which the measurement was performed and shall
contain the date of the seal gap measurement, the raw data obtained in
the measurement process required by paragraph (a)(1)(ii) of this section
and the calculation required by paragraph (a)(1)(iii) of this section.
[[Page 229]]
(E) If either the seal gap calculated in accord with paragraph
(a)(1)(iii) of this section or the measured maximum seal gap exceeds the
limitations specified by Sec. 60.112a of this subpart, a report shall be
furnished to the Administrator within 60 days of the date of
measurements. The report shall identify the vessel and list each reason
why the vessel did not meet the specifications of Sec. 60.112a. The
report shall also describe the actions necessary to bring the storage
vessel into compliance with the specifications of Sec. 60.112a.
(ii) Determine gap widths in the primary and secondary seals
individually by the following procedures:
(A) Measure seal gaps, if any, at one or more floating roof levels
when the roof is floating off the roof leg supports.
(B) Measure seal gaps around the entire circumference of the tank in
each place where a \1/8\" diameter uniform probe passes freely (without
forcing or binding against seal) between the seal and the tank wall and
measure the circumferential distance of each such location.
(C) The total surface area of each gap described in paragraph
(a)(1)(ii)(B) of this section shall be determined by using probes of
various widths to accurately measure the actual distance from the tank
wall to the seal and multiplying each such width by its respective
circumferential distance.
(iii) Add the gap surface area of each gap location for the primary
seal and the secondary seal individually. Divide the sum for each seal
by the nominal diameter of the tank and compare each ratio to the
appropriate ratio in the standard in Sec. 60.112a(a)(1)(i) and
Sec. 60.112a(a)(1)(ii).
(iv) Provide the Administrator 30 days prior notice of the gap
measurement to afford the Administrator the opportunity to have an
observer present.
(2) The owner or operator of each storage vessel to which this
subpart applies which has a vapor recovery and return or disposal system
shall provide the following information to the Administrator on or
before the date on which construction of the storage vessel commences:
(i) Emission data, if available, for a similar vapor recovery and
return or disposal system used on the same type of storage vessel, which
can be used to determine the efficiency of the system. A complete
description of the emission measurement method used must be included.
(ii) The manufacturer's design specifications and estimated emission
reduction capability of the system.
(iii) The operation and maintenance plan for the system.
(iv) Any other information which will be useful to the Administrator
in evaluating the effectiveness of the system in reducing VOC emissions.
[45 FR 23379, Apr. 4, 1980, as amended at 52 FR 11429, Apr. 8, 1987]
Sec. 60.114a Alternative means of emission limitation.
(a) If, in the Administrator's judgment, an alternative means of
emission limitation will achieve a reduction in emissions at least
equivalent to the reduction in emissions achieved by any requirement in
Sec. 60.112a, the Administrator will publish in the Federal Register a
notice permitting the use of the alternative means for purposes of
compliance with that requirement.
(b) Any notice under paragraph (a) of this section will be published
only after notice and an opportunity for a hearing.
(c) Any person seeking permission under this section shall submit to
the Administrator a written application including:
(1) An actual emissions test that uses a full-sized or scale-model
storage vessel that accurately collects and measures all VOC emissions
from a given control device and that accurately simulates wind and
accounts for other emission variables such as temperature and barometric
pressure.
(2) An engineering evaluation that the Administrator determines is
an accurate method of determining equivalence.
(d) The Administrator may condition the permission on requirements
that may be necessary to ensure operation and maintenance to achieve the
same emissions reduction as specified in Sec. 60.112a.
[[Page 230]]
(e) The primary vapor-mounted seal in the ``Volume-Maximizing Seal''
manufactured by R.F.I. Services Corporation is approved as equivalent to
the vapor-mounted seal required by Sec. 60.112a(a)(1)(i) and must meet
the gap criteria specified in Sec. 60.112a(a)(1)(i)(B). There shall be
no gaps between the tank wall and any secondary seal used in conjunction
with the primary seal in the ``Volume-Maximizing Seal''.
[52 FR 11429, Apr. 8, 1987]
Sec. 60.115a Monitoring of operations.
(a) Except as provided in paragraph (d) of this section, the owner
or operator subject to this subpart shall maintain a record of the
petroleum liquid stored, the period of storage, and the maximum true
vapor pressure of that liquid during the respective storage period.
(b) Available data on the typical Reid vapor pressure and the
maximum expected storage temperature of the stored product may be used
to determine the maximum true vapor pressure from nomographs contained
in API Bulletin 2517, unless the Administrator specifically requests
that the liquid be sampled, the actual storage temperature determined,
and the Reid vapor pressure determined from the sample(s).
(c) The true vapor pressure of each type of crude oil with a Reid
vapor pressure less than 13.8 kPa (2.0 psia) or whose physical
properties preclude determination by the recommended method is to be
determined from available data and recorded if the estimated true vapor
pressure is greater than 6.9 kPa (1.0 psia).
(d) The following are exempt from the requirements of this section:
(1) Each owner or operator of each storage vessel storing a
petroleum liquid with a Reid vapor pressure of less than 6.9 kPa (1.0
psia) provided the maximum true vapor pressure does not exceed 6.9 kPa
(1.0 psia).
(2) The owner or operator of each storage vessel equipped with a
vapor recovery and return or disposal system in accordance with the
requirements of Sec. 60.112a(a)(3) and (b), or a closed vent system and
control device meeting the specifications of 40 CFR 65.42(b)(4), (b)(5),
or (c).
[45 FR 23379, Apr. 4, 1980, as amended at 65 FR 78275, Dec. 14, 2000]
Subpart Kb--Standards of Performance for Volatile Organic Liquid Storage
Vessels (Including Petroleum Liquid Storage Vessels) for Which
Construction, Reconstruction, or Modification Commenced After July 23,
1984
Source: 52 FR 11429, Apr. 8, 1987, unless otherwise noted.
Sec. 60.110b Applicability and designation of affected facility.
(a) Except as provided in paragraphs (b), (c), and (d) of this
section, the affected facility to which this subpart applies is each
storage vessel with a capacity greater than or equal to 40 cubic meters
(m3) that is used to store volatile organic liquids (VOL's)
for which construction, reconstruction, or modification is commenced
after July 23, 1984.
(b) Except as specified in paragraphs (a) and (b) of Sec. 60.116b,
storage vessels with design capacity less than 75 m3 are
exempt from the General Provisions (part 60, subpart A) and from the
provisions of this subpart.
(c) Except as specified in paragraphs (a) and (b) of Sec. 60.116b,
vessels either with a capacity greater than or equal to 151 m\3\ storing
a liquid with a maximum true vapor pressure less than 3.5 kPa or with a
capacity greater than or equal to 75 m\3\ but less than 151 m\3\ storing
a liquid with a maximum true vapor pressure less than 15.0 kPa are
exempt from the General Provisions (part 60, subpart A) and from the
provisions of this subpart.
(d) This subpart does not apply to the following:
(1) Vessels at coke oven by-product plants.
(2) Pressure vessels designed to operate in excess of 204.9 kPa and
without emissions to the atmosphere.
(3) Vessels permanently attached to mobile vehicles such as trucks,
railcars, barges, or ships.
[[Page 231]]
(4) Vessels with a design capacity less than or equal to 1,589.874
m3 used for petroleum or condensate stored, processed, or
treated prior to custody transfer.
(5) Vessels located at bulk gasoline plants.
(6) Storage vessels located at gasoline service stations.
(7) Vessels used to store beverage alcohol.
(e) Alternative means of compliance--(1) Option to comply with part
65. Owners or operators may choose to comply with 40 CFR part 65,
subpart C, to satisfy the requirements of Secs. 60.112b through 60.117b
for storage vessels that are subject to this subpart that meet the
specifications in paragraphs (e)(1)(i) and (ii) of this section. When
choosing to comply with 40 CFR part 65, subpart C, the monitoring
requirements of Sec. 60.116b(c), (e), (f)(1), and (g) still apply. Other
provisions applying to owners or operators who choose to comply with 40
CFR part 65 are provided in 40 CFR 65.1.
(i) A storage vessel with a design capacity greater than or equal to
151 m3 containing a VOL that, as stored, has a maximum true
vapor pressure equal to or greater than 5.2 kPa; or
(ii) A storage vessel with a design capacity greater than 75
m3 but less than 151 m3 containing a VOL that, as
stored, has a maximum true vapor pressure equal to or greater than 27.6
kPa.
(2) Part 60, subpart A. Owners or operators who choose to comply
with 40 CFR part 65, subpart C, must also comply with Secs. 60.1, 60.2,
60.5, 60.6, 60.7(a)(1) and (4), 60.14, 60.15, and 60.16 for those
storage vessels. All sections and paragraphs of subpart A of this part
that are not mentioned in this paragraph (e)(2) do not apply to owners
or operators of storage vessels complying with 40 CFR part 65, subpart
C, except that provisions required to be met prior to implementing 40
CFR part 65 still apply. Owners and operators who choose to comply with
40 CFR part 65, subpart C, must comply with 40 CFR part 65, subpart A.
(3) Internal floating roof report. If an owner or operator installs
an internal floating roof and, at initial startup, chooses to comply
with 40 CFR part 65, subpart C, a report shall be furnished to the
Administrator stating that the control equipment meets the
specifications of 40 CFR 65.43. This report shall be an attachment to
the notification required by 40 CFR 65.5(b).
(4) External floating roof report. If an owner or operator installs
an external floating roof and, at initial startup, chooses to comply
with 40 CFR part 65, subpart C, a report shall be furnished to the
Administrator stating that the control equipment meets the
specifications of 40 CFR 65.44. This report shall be an attachment to
the notification required by 40 CFR 65.5(b).
[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989; 65
FR 78275, Dec. 14, 2000]
Sec. 60.111b Definitions.
Terms used in this subpart are defined in the Act, in subpart A of
this part, or in this subpart as follows:
(a) Bulk gasoline plant means any gasoline distribution facility
that has a gasoline throughput less than or equal to 75,700 liters per
day. Gasoline throughput shall be the maximum calculated design
throughput as may be limited by compliance with an enforceable condition
under Federal requirement or Federal, State or local law, and
discoverable by the Administrator and any other person.
(b) Condensate means hydrocarbon liquid separated from natural gas
that condenses due to changes in the temperature or pressure, or both,
and remains liquid at standard conditions.
(c) Custody transfer means the transfer of produced petroleum and/or
condensate, after processing and/or treatment in the producing
operations, from storage vessels or automatic transfer facilities to
pipelines or any other forms of transportation.
(d) Fill means the introduction of VOL into a storage vessel but not
necessarily to complete capacity.
(e) Gasoline service station means any site where gasoline is
dispensed to motor vehicle fuel tanks from stationary storage tanks.
(f) Maximum true vapor pressure means the equilibrium partial
pressure exerted by the stored VOL at the temperature equal to the
highest calendar-month average of the VOL storage temperature for VOL's
stored above or
[[Page 232]]
below the ambient temperature or at the local maximum monthly average
temperature as reported by the National Weather Service for VOL's stored
at the ambient temperature, as determined:
(1) In accordance with methods described in American Petroleum
institute Bulletin 2517, Evaporation Loss From External Floating Roof
Tanks, (incorporated by reference--see Sec. 60.17); or
(2) As obtained from standard reference texts; or
(3) As determined by ASTM D2879-83, 96, or 97 (incorporated by
reference--see Sec. 60.17);
(4) Any other method approved by the Administrator.
(g) Reid vapor pressure means the absolute vapor pressure of
volatile crude oil and volatile nonviscous petroleum liquids except
liquified petroleum gases, as determined by ASTM D323-82 or 94
(incorporated by reference--see Sec. 60.17).
(h) Petroleum means the crude oil removed from the earth and the
oils derived from tar sands, shale, and coal.
(i) Petroleum liquids means petroleum, condensate, and any finished
or intermediate products manufactured in a petroleum refinery.
(j) Storage vessel means each tank, reservoir, or container used for
the storage of volatile organic liquids but does not include:
(1) Frames, housing, auxiliary supports, or other components that
are not directly involved in the containment of liquids or vapors; or
(2) Subsurface caverns or porous rock reservoirs.
(k) Volatile organic liquid (VOL) means any organic liquid which can
emit volatile organic compounds into the atmosphere except those VOL's
that emit only those compounds which the Administrator has determined do
not contribute appreciably to the formation of ozone. These compounds
are identified in EPA statements on ozone abatement policy for SIP
revisions (42 FR 35314, 44 FR 32042, 45 FR 32424, and 45 FR 48941).
(l) Waste means any liquid resulting from industrial, commercial,
mining or agricultural operations, or from community activities that is
discarded or is being accumulated, stored, or physically, chemically, or
biologically treated prior to being discarded or recycled.
[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989; 65
FR 61756, Oct. 17, 2000]
Sec. 60.112b Standard for volatile organic compounds (VOC).
(a) The owner or operator of each storage vessel either with a
design capacity greater than or equal to 151 m\3\ containing a VOL that,
as stored, has a maximum true vapor pressure equal to or greater than
5.2 kPa but less than 76.6 kPa or with a design capacity greater than or
equal to 75 m\3\ but less than 151 m\3\ containing a VOL that, as
stored, has a maximum true vapor pressure equal to or greater than 27.6
kPa but less than 76.6 kPa, shall equip each storage vessel with one of
the following:
(1) A fixed roof in combination with an internal floating roof
meeting the following specifications:
(i) The internal floating roof shall rest or float on the liquid
surface (but not necessarily in complete contact with it) inside a
storage vessel that has a fixed roof. The internal floating roof shall
be floating on the liquid surface at all times, except during initial
fill and during those intervals when the storage vessel is completely
emptied or subsequently emptied and refilled. When the roof is resting
on the leg supports, the process of filling, emptying, or refilling
shall be continuous and shall be accomplished as rapidly as possible.
(ii) Each internal floating roof shall be equipped with one of the
following closure devices between the wall of the storage vessel and the
edge of the internal floating roof:
(A) A foam- or liquid-filled seal mounted in contact with the liquid
(liquid-mounted seal). A liquid-mounted seal means a foam- or liquid-
filled seal mounted in contact with the liquid between the wall of the
storage vessel and the floating roof continuously around the
circumference of the tank.
(B) Two seals mounted one above the other so that each forms a
continuous closure that completely covers the space between the wall of
the storage
[[Page 233]]
vessel and the edge of the internal floating roof. The lower seal may be
vapor-mounted, but both must be continuous.
(C) A mechanical shoe seal. A mechanical shoe seal is a metal sheet
held vertically against the wall of the storage vessel by springs or
weighted levers and is connected by braces to the floating roof. A
flexible coated fabric (envelope) spans the annular space between the
metal sheet and the floating roof.
(iii) Each opening in a noncontact internal floating roof except for
automatic bleeder vents (vacuum breaker vents) and the rim space vents
is to provide a projection below the liquid surface.
(iv) Each opening in the internal floating roof except for leg
sleeves, automatic bleeder vents, rim space vents, column wells, ladder
wells, sample wells, and stub drains is to be equipped with a cover or
lid which is to be maintained in a closed position at all times (i.e.,
no visible gap) except when the device is in actual use. The cover or
lid shall be equipped with a gasket. Covers on each access hatch and
automatic gauge float well shall be bolted except when they are in use.
(v) Automatic bleeder vents shall be equipped with a gasket and are
to be closed at all times when the roof is floating except when the roof
is being floated off or is being landed on the roof leg supports.
(vi) Rim space vents shall be equipped with a gasket and are to be
set to open only when the internal floating roof is not floating or at
the manufacturer's recommended setting.
(vii) Each penetration of the internal floating roof for the purpose
of sampling shall be a sample well. The sample well shall have a slit
fabric cover that covers at least 90 percent of the opening.
(viii) Each penetration of the internal floating roof that allows
for passage of a column supporting the fixed roof shall have a flexible
fabric sleeve seal or a gasketed sliding cover.
(ix) Each penetration of the internal floating roof that allows for
passage of a ladder shall have a gasketed sliding cover.
(2) An external floating roof. An external floating roof means a
pontoon-type or double-deck type cover that rests on the liquid surface
in a vessel with no fixed roof. Each external floating roof must meet
the following specifications:
(i) Each external floating roof shall be equipped with a closure
device between the wall of the storage vessel and the roof edge. The
closure device is to consist of two seals, one above the other. The
lower seal is referred to as the primary seal, and the upper seal is
referred to as the secondary seal.
(A) The primary seal shall be either a mechanical shoe seal or a
liquid-mounted seal. Except as provided in Sec. 60.113b(b)(4), the seal
shall completely cover the annular space between the edge of the
floating roof and tank wall.
(B) The secondary seal shall completely cover the annular space
between the external floating roof and the wall of the storage vessel in
a continuous fashion except as allowed in Sec. 60.113b(b)(4).
(ii) Except for automatic bleeder vents and rim space vents, each
opening in a noncontact external floating roof shall provide a
projection below the liquid surface. Except for automatic bleeder vents,
rim space vents, roof drains, and leg sleeves, each opening in the roof
is to be equipped with a gasketed cover, seal, or lid that is to be
maintained in a closed position at all times (i.e., no visible gap)
except when the device is in actual use. Automatic bleeder vents are to
be closed at all times when the roof is floating except when the roof is
being floated off or is being landed on the roof leg supports. Rim vents
are to be set to open when the roof is being floated off the roof legs
supports or at the manufacturer's recommended setting. Automatic bleeder
vents and rim space vents are to be gasketed. Each emergency roof drain
is to be provided with a slotted membrane fabric cover that covers at
least 90 percent of the area of the opening.
(iii) The roof shall be floating on the liquid at all times (i.e.,
off the roof leg supports) except during initial fill until the roof is
lifted off leg supports and when the tank is completely emptied and
subsequently refilled. The process of filling, emptying, or refilling
[[Page 234]]
when the roof is resting on the leg supports shall be continuous and
shall be accomplished as rapidly as possible.
(3) A closed vent system and control device meeting the following
specifications:
(i) The closed vent system shall be designed to collect all VOC
vapors and gases discharged from the storage vessel and operated with no
detectable emissions as indicated by an instrument reading of less than
500 ppm above background and visual inspections, as determined in part
60, subpart VV, Sec. 60.485(b).
(ii) The control device shall be designed and operated to reduce
inlet VOC emissions by 95 percent or greater. If a flare is used as the
control device, it shall meet the specifications described in the
general control device requirements (Sec. 60.18) of the General
Provisions.
(4) A system equivalent to those described in paragraphs (a)(1),
(a)(2), or (a)(3) of this section as provided in Sec. 60.114b of this
subpart.
(b) The owner or operator of each storage vessel with a design
capacity greater than or equal to 75 m3 which contains a VOL
that, as stored, has a maximum true vapor pressure greater than or equal
to 76.6 kPa shall equip each storage vessel with one of the following:
(1) A closed vent system and control device as specified in
Sec. 60.112b(a)(3).
(2) A system equivalent to that described in paragraph (b)(1) as
provided in Sec. 60.114b of this subpart.
(c) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant
in Elkton, Virginia. This paragraph applies only to the pharmaceutical
manufacturing facility, commonly referred to as the Stonewall Plant,
located at Route 340 South, in Elkton, Virginia (``site'').
(1) For any storage vessel that otherwise would be subject to the
control technology requirements of paragraphs (a) or (b) of this
section, the site shall have the option of either complying directly
with the requirements of this subpart, or reducing the site-wide total
criteria pollutant emissions cap (total emissions cap) in accordance
with the procedures set forth in a permit issued pursuant to 40 CFR
52.2454. If the site chooses the option of reducing the total emissions
cap in accordance with the procedures set forth in such permit, the
requirements of such permit shall apply in lieu of the otherwise
applicable requirements of this subpart for such storage vessel.
(2) For any storage vessel at the site not subject to the
requirements of 40 CFR 60.112b (a) or (b), the requirements of 40 CFR
60.116b (b) and (c) and the General Provisions (subpart A of this part)
shall not apply.
[52 FR 11429, Apr. 8, 1987, as amended at 62 FR 52641, Oct. 8, 1997]
Sec. 60.113b Testing and procedures.
The owner or operator of each storage vessel as specified in
Sec. 60.112b(a) shall meet the requirements of paragraph (a), (b), or
(c) of this section. The applicable paragraph for a particular storage
vessel depends on the control equipment installed to meet the
requirements of Sec. 60.112b.
(a) After installing the control equipment required to meet
Sec. 60.112b(a)(1) (permanently affixed roof and internal floating
roof), each owner or operator shall:
(1) Visually inspect the internal floating roof, the primary seal,
and the secondary seal (if one is in service), prior to filling the
storage vessel with VOL. If there are holes, tears, or other openings in
the primary seal, the secondary seal, or the seal fabric or defects in
the internal floating roof, or both, the owner or operator shall repair
the items before filling the storage vessel.
(2) For Vessels equipped with a liquid-mounted or mechanical shoe
primary seal, visually inspect the internal floating roof and the
primary seal or the secondary seal (if one is in service) through
manholes and roof hatches on the fixed roof at least once every 12
months after initial fill. If the internal floating roof is not resting
on the surface of the VOL inside the storage vessel, or there is liquid
accumulated on the roof, or the seal is detached, or there are holes or
tears in the seal fabric, the owner or operator shall repair the items
or empty and remove the storage vessel from service within 45 days. If a
failure that is detected during inspections required in this paragraph
cannot be repaired within 45
[[Page 235]]
days and if the vessel cannot be emptied within 45 days, a 30-day
extension may be requested from the Administrator in the inspection
report required in Sec. 60.115b(a)(3). Such a request for an extension
must document that alternate storage capacity is unavailable and specify
a schedule of actions the company will take that will assure that the
control equipment will be repaired or the vessel will be emptied as soon
as possible.
(3) For vessels equipped with a double-seal system as specified in
Sec. 60.112b(a)(1)(ii)(B):
(i) Visually inspect the vessel as specified in paragraph (a)(4) of
this section at least every 5 years; or
(ii) Visually inspect the vessel as specified in paragraph (a)(2) of
this section.
(4) Visually inspect the internal floating roof, the primary seal,
the secondary seal (if one is in service), gaskets, slotted membranes
and sleeve seals (if any) each time the storage vessel is emptied and
degassed. If the internal floating roof has defects, the primary seal
has holes, tears, or other openings in the seal or the seal fabric, or
the secondary seal has holes, tears, or other openings in the seal or
the seal fabric, or the gaskets no longer close off the liquid surfaces
from the atmosphere, or the slotted membrane has more than 10 percent
open area, the owner or operator shall repair the items as necessary so
that none of the conditions specified in this paragraph exist before
refilling the storage vessel with VOL. In no event shall inspections
conducted in accordance with this provision occur at intervals greater
than 10 years in the case of vessels conducting the annual visual
inspection as specified in paragraphs (a)(2) and (a)(3)(ii) of this
section and at intervals no greater than 5 years in the case of vessels
specified in paragraph (a)(3)(i) of this section.
(5) Notify the Administrator in writing at least 30 days prior to
the filling or refilling of each storage vessel for which an inspection
is required by paragraphs (a)(1) and (a)(4) of this section to afford
the Administrator the opportunity to have an observer present. If the
inspection required by paragraph (a)(4) of this section is not planned
and the owner or operator could not have known about the inspection 30
days in advance or refilling the tank, the owner or operator shall
notify the Administrator at least 7 days prior to the refilling of the
storage vessel. Notification shall be made by telephone immediately
followed by written documentation demonstrating why the inspection was
unplanned. Alternatively, this notification including the written
documentation may be made in writing and sent by express mail so that it
is received by the Administrator at least 7 days prior to the refilling.
(b) After installing the control equipment required to meet
Sec. 60.112b(a)(2) (external floating roof), the owner or operator
shall:
(1) Determine the gap areas and maximum gap widths, between the
primary seal and the wall of the storage vessel and between the
secondary seal and the wall of the storage vessel according to the
following frequency.
(i) Measurements of gaps between the tank wall and the primary seal
(seal gaps) shall be performed during the hydrostatic testing of the
vessel or within 60 days of the initial fill with VOL and at least once
every 5 years thereafter.
(ii) Measurements of gaps between the tank wall and the secondary
seal shall be performed within 60 days of the initial fill with VOL and
at least once per year thereafter.
(iii) If any source ceases to store VOL for a period of 1 year or
more, subsequent introduction of VOL into the vessel shall be considered
an initial fill for the purposes of paragraphs (b)(1)(i) and (b)(1)(ii)
of this section.
(2) Determine gap widths and areas in the primary and secondary
seals individually by the following procedures:
(i) Measure seal gaps, if any, at one or more floating roof levels
when the roof is floating off the roof leg supports.
(ii) Measure seal gaps around the entire circumference of the tank
in each place where a 0.32-cm diameter uniform probe passes freely
(without forcing or binding against seal) between the seal and the wall
of the storage vessel and measure the circumferential distance of each
such location.
[[Page 236]]
(iii) The total surface area of each gap described in paragraph
(b)(2)(ii) of this section shall be determined by using probes of
various widths to measure accurately the actual distance from the tank
wall to the seal and multiplying each such width by its respective
circumferential distance.
(3) Add the gap surface area of each gap location for the primary
seal and the secondary seal individually and divide the sum for each
seal by the nominal diameter of the tank and compare each ratio to the
respective standards in paragraph (b)(4) of this section.
(4) Make necessary repairs or empty the storage vessel within 45
days of identification in any inspection for seals not meeting the
requirements listed in (b)(4) (i) and (ii) of this section:
(i) The accumulated area of gaps between the tank wall and the
mechanical shoe or liquid-mounted primary seal shall not exceed 212
Cm\2\ per meter of tank diameter, and the width of any portion of any
gap shall not exceed 3.81 cm.
(A) One end of the mechanical shoe is to extend into the stored
liquid, and the other end is to extend a minimum vertical distance of 61
cm above the stored liquid surface.
(B) There are to be no holes, tears, or other openings in the shoe,
seal fabric, or seal envelope.
(ii) The secondary seal is to meet the following requirements:
(A) The secondary seal is to be installed above the primary seal so
that it completely covers the space between the roof edge and the tank
wall except as provided in paragraph (b)(2)(iii) of this section.
(B) The accumulated area of gaps between the tank wall and the
secondary seal shall not exceed 21.2 cm2 per meter of tank
diameter, and the width of any portion of any gap shall not exceed 1.27
cm.
(C) There are to be no holes, tears, or other openings in the seal
or seal fabric.
(iii) If a failure that is detected during inspections required in
paragraph (b)(1) of Sec. 60.113b(b) cannot be repaired within 45 days
and if the vessel cannot be emptied within 45 days, a 30-day extension
may be requested from the Administrator in the inspection report
required in Sec. 60.115b(b)(4). Such extension request must include a
demonstration of unavailability of alternate storage capacity and a
specification of a schedule that will assure that the control equipment
will be repaired or the vessel will be emptied as soon as possible.
(5) Notify the Administrator 30 days in advance of any gap
measurements required by paragraph (b)(1) of this section to afford the
Administrator the opportunity to have an observer present.
(6) Visually inspect the external floating roof, the primary seal,
secondary seal, and fittings each time the vessel is emptied and
degassed.
(i) If the external floating roof has defects, the primary seal has
holes, tears, or other openings in the seal or the seal fabric, or the
secondary seal has holes, tears, or other openings in the seal or the
seal fabric, the owner or operator shall repair the items as necessary
so that none of the conditions specified in this paragraph exist before
filling or refilling the storage vessel with VOL.
(ii) For all the inspections required by paragraph (b)(6) of this
section, the owner or operator shall notify the Administrator in writing
at least 30 days prior to the filling or refilling of each storage
vessel to afford the Administrator the opportunity to inspect the
storage vessel prior to refilling. If the inspection required by
paragraph (b)(6) of this section is not planned and the owner or
operator could not have known about the inspection 30 days in advance of
refilling the tank, the owner or operator shall notify the Administrator
at least 7 days prior to the refilling of the storage vessel.
Notification shall be made by telephone immediately followed by written
documentation demonstrating why the inspection was unplanned.
Alternatively, this notification including the written documentation may
be made in writing and sent by express mail so that it is received by
the Administrator at least 7 days prior to the refilling.
(c) The owner or operator of each source that is equipped with a
closed vent system and control device as required in Sec. 60.112b (a)(3)
or (b)(2) (other than a flare) is exempt from Sec. 60.8 of
[[Page 237]]
the General Provisions and shall meet the following requirements.
(1) Submit for approval by the Administrator as an attachment to the
notification required by Sec. 60.7(a)(1) or, if the facility is exempt
from Sec. 60.7(a)(1), as an attachment to the notification required by
Sec. 60.7(a)(2), an operating plan containing the information listed
below.
(i) Documentation demonstrating that the control device will achieve
the required control efficiency during maximum loading conditions. This
documentation is to include a description of the gas stream which enters
the control device, including flow and VOC content under varying liquid
level conditions (dynamic and static) and manufacturer's design
specifications for the control device. If the control device or the
closed vent capture system receives vapors, gases, or liquids other than
fuels from sources that are not designated sources under this subpart,
the efficiency demonstration is to include consideration of all vapors,
gases, and liquids received by the closed vent capture system and
control device. If an enclosed combustion device with a minimum
residence time of 0.75 seconds and a minimum temperature of 816 deg.C
is used to meet the 95 percent requirement, documentation that those
conditions will exist is sufficient to meet the requirements of this
paragraph.
(ii) A description of the parameter or parameters to be monitored to
ensure that the control device will be operated in conformance with its
design and an explanation of the criteria used for selection of that
parameter (or parameters).
(2) Operate the closed vent system and control device and monitor
the parameters of the closed vent system and control device in
accordance with the operating plan submitted to the Administrator in
accordance with paragraph (c)(1) of this section, unless the plan was
modified by the Administrator during the review process. In this case,
the modified plan applies.
(d) The owner or operator of each source that is equipped with a
closed vent system and a flare to meet the requirements in Sec. 60.112b
(a)(3) or (b)(2) shall meet the requirements as specified in the general
control device requirements, Sec. 60.18 (e) and (f).
[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989]
Sec. 60.114b Alternative means of emission limitation.
(a) If, in the Administrator's judgment, an alternative means of
emission limitation will achieve a reduction in emissions at least
equivalent to the reduction in emissions achieved by any requirement in
Sec. 60.112b, the Administrator will publish in the Federal Register a
notice permitting the use of the alternative means for purposes of
compliance with that requirement.
(b) Any notice under paragraph (a) of this section will be published
only after notice and an opportunity for a hearing.
(c) Any person seeking permission under this section shall submit to
the Administrator a written application including:
(1) An actual emissions test that uses a full-sized or scale-model
storage vessel that accurately collects and measures all VOC emissions
from a given control device and that accurately simulates wind and
accounts for other emission variables such as temperature and barometric
pressure.
(2) An engineering evaluation that the Administrator determines is
an accurate method of determining equivalence.
(d) The Administrator may condition the permission on requirements
that may be necessary to ensure operation and maintenance to achieve the
same emissions reduction as specified in Sec. 60.112b.
Sec. 60.115b Reporting and recordkeeping requirements.
The owner or operator of each storage vessel as specified in
Sec. 60.112b(a) shall keep records and furnish reports as required by
paragraphs (a), (b), or (c) of this section depending upon the control
equipment installed to meet the requirements of Sec. 60.112b. The owner
or operator shall keep copies of all reports and records required by
this section, except for the record required by (c)(1), for at least 2
years. The record required by (c)(1) will be kept for the life of the
control equipment.
[[Page 238]]
(a) After installing control equipment in accordance with
Sec. 60.112b(a)(1) (fixed roof and internal floating roof), the owner or
operator shall meet the following requirements.
(1) Furnish the Administrator with a report that describes the
control equipment and certifies that the control equipment meets the
specifications of Sec. 60.112b(a)(1) and Sec. 60.113b(a)(1). This report
shall be an attachment to the notification required by Sec. 60.7(a)(3).
(2) Keep a record of each inspection performed as required by
Sec. 60.113b (a)(1), (a)(2), (a)(3), and (a)(4). Each record shall
identify the storage vessel on which the inspection was performed and
shall contain the date the vessel was inspected and the observed
condition of each component of the control equipment (seals, internal
floating roof, and fittings).
(3) If any of the conditions described in Sec. 60.113b(a)(2) are
detected during the annual visual inspection required by
Sec. 60.113b(a)(2), a report shall be furnished to the Administrator
within 30 days of the inspection. Each report shall identify the storage
vessel, the nature of the defects, and the date the storage vessel was
emptied or the nature of and date the repair was made.
(4) After each inspection required by Sec. 60.113b(a)(3) that finds
holes or tears in the seal or seal fabric, or defects in the internal
floating roof, or other control equipment defects listed in
Sec. 60.113b(a)(3)(ii), a report shall be furnished to the Administrator
within 30 days of the inspection. The report shall identify the storage
vessel and the reason it did not meet the specifications of
Sec. 61.112b(a)(1) or Sec. 60.113b(a)(3) and list each repair made.
(b) After installing control equipment in accordance with
Sec. 61.112b(a)(2) (external floating roof), the owner or operator shall
meet the following requirements.
(1) Furnish the Administrator with a report that describes the
control equipment and certifies that the control equipment meets the
specifications of Sec. 60.112b(a)(2) and Sec. 60.113b(b)(2), (b)(3), and
(b)(4). This report shall be an attachment to the notification required
by Sec. 60.7(a)(3).
(2) Within 60 days of performing the seal gap measurements required
by Sec. 60.113b(b)(1), furnish the Administrator with a report that
contains:
(i) The date of measurement.
(ii) The raw data obtained in the measurement.
(iii) The calculations described in Sec. 60.113b (b)(2) and (b)(3).
(3) Keep a record of each gap measurement performed as required by
Sec. 60.113b(b). Each record shall identify the storage vessel in which
the measurement was performed and shall contain:
(i) The date of measurement.
(ii) The raw data obtained in the measurement.
(iii) The calculations described in Sec. 60.113b (b)(2) and (b)(3).
(4) After each seal gap measurement that detects gaps exceeding the
limitations specified by Sec. 60.113b(b)(4), submit a report to the
Administrator within 30 days of the inspection. The report will identify
the vessel and contain the information specified in paragraph (b)(2) of
this section and the date the vessel was emptied or the repairs made and
date of repair.
(c) After installing control equipment in accordance with
Sec. 60.112b (a)(3) or (b)(1) (closed vent system and control device
other than a flare), the owner or operator shall keep the following
records.
(1) A copy of the operating plan.
(2) A record of the measured values of the parameters monitored in
accordance with Sec. 60.113b(c)(2).
(d) After installing a closed vent system and flare to comply with
Sec. 60.112b, the owner or operator shall meet the following
requirements.
(1) A report containing the measurements required by Sec. 60.18(f)
(1), (2), (3), (4), (5), and (6) shall be furnished to the Administrator
as required by Sec. 60.8 of the General Provisions. This report shall be
submitted within 6 months of the initial start-up date.
(2) Records shall be kept of all periods of operation during which
the flare pilot flame is absent.
(3) Semiannual reports of all periods recorded under
Sec. 60.115b(d)(2) in which the pilot flame was absent shall be
furnished to the Administrator.
[[Page 239]]
Sec. 60.116b Monitoring of operations.
(a) The owner or operator shall keep copies of all records required
by this section, except for the record required by paragraph (b) of this
section, for at least 2 years. The record required by paragraph (b) of
this section will be kept for the life of the source.
(b) The owner or operator of each storage vessel as specified in
Sec. 60.110b(a) shall keep readily accessible records showing the
dimension of the storage vessel and an analysis showing the capacity of
the storage vessel. Each storage vessel with a design capacity less than
75 m3 is subject to no provision of this subpart other than
those required by this paragraph.
(c) Except as provided in paragraphs (f) and (g) of this section,
the owner or operator of each storage vessel either with a design
capacity greater than or equal to 151 m3 storing a liquid
with a maximum true vapor pressure greater than or equal to 3.5 kPa or
with a design capacity greater than or equal to 75 m3 but
less than 151 m3 storing a liquid with a maximum true vapor
pressure greater than or equal to 15.0 kPa shall maintain a record of
the VOL stored, the period of storage, and the maximum true vapor
pressure of that VOL during the respective storage period.
(d) Except as provided in paragraph (g) of this section, the owner
or operator of each storage vessel either with a design capacity greater
than or equal to 151 m3 storing a liquid with a maximum true
vapor pressure that is normally less than 5.2 kPa or with a design
capacity greater than or equal to 75 m3 but less than 151
m3 storing a liquid with a maximum true vapor pressure that
is normally less than 27.6 kPa shall notify the Administrator within 30
days when the maximum true vapor pressure of the liquid exceeds the
respective maximum true vapor vapor pressure values for each volume
range.
(e) Available data on the storage temperature may be used to
determine the maximum true vapor pressure as determined below.
(1) For vessels operated above or below ambient temperatures, the
maximum true vapor pressure is calculated based upon the highest
expected calendar-month average of the storage temperature. For vessels
operated at ambient temperatures, the maximum true vapor pressure is
calculated based upon the maximum local monthly average ambient
temperature as reported by the National Weather Service.
(2) For crude oil or refined petroleum products the vapor pressure
may be obtained by the following:
(i) Available data on the Reid vapor pressure and the maximum
expected storage temperature based on the highest expected calendar-
month average temperature of the stored product may be used to determine
the maximum true vapor pressure from nomographs contained in API
Bulletin 2517 (incorporated by reference--see Sec. 60.17), unless the
Administrator specifically requests that the liquid be sampled, the
actual storage temperature determined, and the Reid vapor pressure
determined from the sample(s).
(ii) The true vapor pressure of each type of crude oil with a Reid
vapor pressure less than 13.8 kPa or with physical properties that
preclude determination by the recommended method is to be determined
from available data and recorded if the estimated maximum true vapor
pressure is greater than 3.5 kPa.
(3) For other liquids, the vapor pressure:
(i) May be obtained from standard reference texts, or
(ii) Determined by ASTM D2879-83, 96, or 97 (incorporated by
reference--see Sec. 60.17); or
(iii) Measured by an appropriate method approved by the
Administrator; or
(iv) Calculated by an appropriate method approved by the
Administrator.
(f) The owner or operator of each vessel storing a waste mixture of
indeterminate or variable composition shall be subject to the following
requirements.
(1) Prior to the initial filling of the vessel, the highest maximum
true vapor pressure for the range of anticipated liquid compositions to
be stored will be determined using the methods described in paragraph
(e) of this section.
[[Page 240]]
(2) For vessels in which the vapor pressure of the anticipated
liquid composition is above the cutoff for monitoring but below the
cutoff for controls as defined in Sec. 60.112b(a), an initial physical
test of the vapor pressure is required; and a physical test at least
once every 6 months thereafter is required as determined by the
following methods:
(i) ASTM D2879-83, 96, or 97 (incorporated by reference--see
Sec. 60.17); or
(ii) ASTM D323-82 or 94 (incorporated by reference--see Sec. 60.17);
or
(iii) As measured by an appropriate method as approved by the
Administrator.
(g) The owner or operator of each vessel equipped with a closed vent
system and control device meeting the specification of Sec. 60.112b or
with emissions reductions equipment as specified in 40 CFR 65.42(b)(4),
(b)(5), (b)(6), or (c) is exempt from the requirements of paragraphs (c)
and (d) of this section.
[52 FR 11429, Apr. 8, 1987, as amended at 65 FR 61756, Oct. 17, 2000; 65
FR 78276, Dec. 14, 2000]
Sec. 60.117b Delegation of authority.
(a) In delegating implementation and enforcement authority to a
State under section 111(c) of the Act, the authorities contained in
paragraph (b) of this section shall be retained by the Administrator and
not transferred to a State.
(b) Authorities which will not be delegated to States:
Secs. 60.111b(f)(4), 60.114b, 60.116b(e)(3)(iii), 60.116b(e)(3)(iv), and
60.116b(f)(2)(iii).
[52 FR 11429, Apr. 8, 1987, as amended at 52 FR 22780, June 16, 1987]
Subpart L--Standards of Performance for Secondary Lead Smelters
Sec. 60.120 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to the following
affected facilities in secondary lead smelters: Pot furnaces of more
than 250 kg (550 lb) charging capacity, blast (cupola) furnaces, and
reverberatory furnaces.
(b) Any facility under paragraph (a) of this section that commences
construction or modification after June 11, 1973, is subject to the
requirements of this subpart.
[42 FR 37937, July 25, 1977]